High power laser flow assurance systems, tools and methods

ABSTRACT

A high power laser system for providing laser beams in various laser beam patterns along a laser beam path that is positioned to provide for the in situ laser processing of materials in tubulars, such as pipes in a hydrocarbon producing well. Laser treating for providing flow assurance by direct and indirect laser processing of materials interfering with flow.

This application: (i) claims under U.S.C. §119(e)(1), the benefit of thefiling date of Mar. 15, 2013 of provisional application Ser. No.61/786,687; (ii) claims under U.S.C. §119(e)(1), the benefit of thefiling date of Mar. 15, 2013 of provisional application Ser. No.61/786,763; (iii) is a continuation-in-part of U.S. patent applicationSer. No. 13/222,931 filed Aug. 31, 2011, which claims under 35 U.S.C.§119(e)(1), the benefit of the filing date of Aug. 31, 2010 ofprovisional application Ser. No. 61/378,910; (iv) is acontinuation-in-part of U.S. patent application Ser. No. 13/565,345filed Aug. 2, 2012, which claims under 35 U.S.C. §119(e)(1), the benefitof the filing date of Mar. 1, 2012 of provisional application Ser. No.61/605,422; (v) is a continuation-in-part of U.S. patent applicationSer. No. 13/347,445 filed Jan. 10, 2012, which claims under 35 U.S.C.§119(e)(1), the benefit of the filing date of Feb. 7, 2011 ofprovisional application Ser. No. 61/431,830; (vi) is acontinuation-in-part of U.S. patent application Ser. No. 13/403,741filed Feb. 23, 2012, which claims under 35 U.S.C. §119(e)(1), thebenefit of the filing date of Feb. 24, 2011 of provisional applicationSer. No. 61/446,312; (vii) is a continuation-in-part of U.S. patentapplication Ser. No. 12/543,986 filed Aug. 19, 2009, which claims under35 U.S.C. §119(e)(1) the benefit of the filing date of Feb. 17, 2009 ofU.S. provisional application Ser. No. 61/153,271, the benefit of thefiling date of Oct. 17, 2008 of U.S. provisional application Ser. No.61/106,472, the benefit of the filing date of Oct. 3, 2008 of U.S.provisional application Ser. No. 61/102,730, and the benefit of thefiling date of Aug. 20, 2008 of U.S. provisional application Ser. No.61/090,384; and (viii) is a continuation-in-part of U.S. patentapplication Ser. No. 14/099,948 filed Dec. 7, 2013, which claims under35 U.S.C. §119(e)(1) the benefit of the filing date of Mar. 15, 2013 ofU.S. provisional application Ser. No. 61/786,763 and the benefit of thefiling date of Dec. 7, 2012 of U.S. provisional application Ser. No.61/734,809, the entire disclosures of each of which are incorporatedherein by reference.

BACKGROUND OF THE INVENTION Field of the Invention

The present inventions relate to methods, apparatus and systems for thedelivery of high power laser beams over a distance to a conduit, pipe,pipeline, production tubing, tubular or other device used for theflowing or transporting of a material, to perform laser and laserassisted operations, such as, cleaning, removing, ablating, fracturing,treating, melting, cleaving, and combinations and various of these.

As used herein the term “earth” should be given its broadest possiblemeaning, and includes, the ground, all natural materials, such as rocks,and artificial materials, such as concrete, that are or may be found inthe ground, including without limitation rock layer formations, such as,granite, basalt, sandstone, dolomite, sand, salt, limestone, ores,minerals, overburden, marble, rhyolite, quartzite and shale rock.

As used herein, unless specified otherwise, the terms “well,” “tunnel”and “borehole” and similar such terms should be given their broadestpossible meaning and include any opening that is created in the earth,in a structure (e.g., building, protected military installation, nuclearplant, or ship), in a work surface, or in a structure in the ground,(e.g., foundation, roadway, airstrip, cave or subterranean structure)that is substantially longer than it is wide, such as a well, a tunnel,a hole, a well bore, a well hole, a micro hole, slimhole and other termscommonly used or known in the arts to define these types of narrow longpassages. These terms would further include, for example, exploratory,production, abandoned, reentered, reworked, and injection wells.

Boreholes may further have segments or sections that have differentorientations, they may have straight sections and arcuate sections andcombinations thereof; and for example may be of the shapes commonlyfound when directional drilling is employed. Thus, as used herein unlessexpressly provided otherwise, the “bottom” of a borehole, the “bottomsurface” of the borehole and similar terms refer to the end of theborehole, i.e., that portion of the borehole farthest along the path ofthe borehole from the borehole's opening, the surface of the earth, orthe borehole's beginning.

As used herein, unless specified otherwise “high power laser energy”means a laser beam having at least about 1 kW (kilowatt) of power. Asused herein, unless specified otherwise “great distances” means at leastabout 500 m (meter). As used herein the term “substantial loss ofpower,” “substantial power loss” and similar such phrases, mean a lossof power of more than about 3.0 dB/km (decibel/kilometer) for a selectedwavelength. As used herein the term “substantial power transmission”means at least about 50% transmittance.

As used herein the term “drill pipe” is to be given its broadestpossible meaning and includes all forms of pipe used for drillingactivities; and refers to a single section or piece of pipe. As usedherein the terms “stand of drill pipe,” “drill pipe stand,” “stand ofpipe,” “stand” and similar type terms should be given their broadestpossible meaning and include two, three or four sections of drill pipethat have been connected, e.g., joined together, typically by jointshaving threaded connections. As used herein the terms “drill string,”“string,” “string of drill pipe,” string of pipe” and similar type termsshould be given their broadest definition and would include a stand orstands joined together for the purpose of being employed in a borehole.Thus, a drill string could include many stands and many hundreds ofsections of drill pipe.

As used herein the term “tubular” is to be given its broadest possiblemeaning and includes drill pipe, casing, riser, coiled tube, compositetube, vacuum insulated tubing (“VIT), production tubing and any similarstructures having at least one channel therein that are, or could beused, in the drilling industry. As used herein the term “joint” is to begiven its broadest possible meaning and includes all types of devices,systems, methods, structures and components used to connect tubularstogether, such as for example, threaded pipe joints and bolted flanges.For drill pipe joints, the joint section typically has a thicker wallthan the rest of the drill pipe. As used herein the thickness of thewall of tubular is the thickness of the material between the internaldiameter of the tubular and the external diameter of the tubular.

As used herein, unless specified otherwise the terms “blowoutpreventer,” “BOP,” and “BOP stack” should be given their broadestpossible meaning, and include: (i) devices positioned at or near theborehole surface, e.g., the surface of the earth including dry land orthe seafloor, which are used to contain or manage pressures or flowsassociated with a borehole; (ii) devices for containing or managingpressures or flows in a borehole that are associated with a subsea riseror a connector; (iii) devices having any number and combination ofgates, valves or elastomeric packers for controlling or managingborehole pressures or flows; (iv) a subsea BOP stack, which stack couldcontain, for example, ram shears, pipe rams, blind rams and annularpreventers; and, (v) other such similar combinations and assemblies offlow and pressure management devices to control borehole pressures,flows or both and, in particular, to control or manage emergency flow orpressure situations.

As used herein, unless specified otherwise “offshore” and “offshoredrilling activities” and similar such terms are used in their broadestsense and would include drilling activities on, or in, any body ofwater, whether fresh or salt water, whether manmade or naturallyoccurring, such as for example rivers, lakes, canals, inland seas,oceans, seas, such as the North Sea, bays and gulfs, such as the Gulf ofMexico. As used herein, unless specified otherwise the term “offshoredrilling rig” is to be given its broadest possible meaning and wouldinclude fixed towers, tenders, platforms, barges, jack-ups, floatingplatforms, drill ships, dynamically positioned drill ships,semi-submersibles and dynamically positioned semi-submersibles. As usedherein, unless specified otherwise the term “seafloor” is to be givenits broadest possible meaning and would include any surface of the earththat lies under, or is at the bottom of, any body of water, whetherfresh or salt water, whether manmade or naturally occurring.

As used herein, unless specified otherwise the term “fixed platform,”would include any structure that has at least a portion of its weightsupported by the seafloor. Fixed platforms would include structures suchas: free-standing caissons, well-protector jackets, pylons, bracedcaissons, piled-jackets, skirted piled-jackets, compliant towers,gravity structures, gravity based structures, skirted gravitystructures, concrete gravity structures, concrete deep water structuresand other combinations and variations of these. Fixed platforms extendfrom at or below the seafloor to and above the surface of the body ofwater, e.g., sea level. Deck structures are positioned above the surfaceof the body of water a top of vertical support members that extend downin to the water to the seafloor.

As used herein the term “pipeline” should be given its broadest possiblemeaning, and includes any structure that contains a channel having alength that is many orders of magnitude greater than its cross-sectionalarea and which is for, or capable of, transporting a material along atleast a portion of the length of the channel. Pipelines may be manymiles long and may be many hundreds of miles long. Pipelines may belocated below the earth, above the earth, under water, within astructure, or combinations of these and other locations. Pipelines maybe made from metal, steel, plastics, ceramics, composite materials, orother materials and compositions know to the pipeline arts and may haveexternal and internal coatings, known to the pipeline arts. In general,pipelines may have internal diameters that range from about 2 to about60 inches although larger and smaller diameters may be utilized. Ingeneral natural gas pipelines may have internal diameters ranging fromabout 2 to 60 inches and oil pipelines have internal diameters rangingfrom about 4 to 48 inches. Pipelines may be used to transmit numeroustypes of materials, in the form of a liquid, gas, fluidized solid,slurry or combinations thereof. Thus, for example pipelines may carryhydrocarbons; chemicals; oil; petroleum products; gasoline; ethanol;biofuels; water; drinking water; irrigation water; cooling water; waterfor hydroelectric power generation; water, or other fluids forgeothermal power generation; natural gas; paints; slurries, such asmineral slurries, coal slurries, pulp slurries; and ore slurries; gases,such as nitrogen and hydrogen; cosmetics; pharmaceuticals; and foodproducts, such as beer.

Pipelines may be, in part, characterized as gathering pipelines,transportation pipelines and distribution pipelines, although thesecharacterizations may be blurred and may not cover all potential typesof pipelines. Gathering pipelines are a number of smaller interconnectedpipelines that form a network of pipelines for bringing together anumber of sources, such as for example bringing together hydrocarbonsbeing produced from a number of wells. Transportation pipelines are whatcan be considered as a traditional pipeline for moving products overlonger distances for example between two cities, two countries, and aproduction location and a shipping, storage or distribution location.The Alaskan oil pipeline is an example of a transportation pipeline.Distribution pipelines can be small pipelines that are made up ofseveral interconnected pipelines and are used for the distribution tofor example an end user, of the material that is being delivered by thepipeline, such as for example the feeder lines used to provide naturalgas to individual homes. As used herein the term pipeline includes allof these and other characterizations of pipelines that are known to orused in the pipeline arts.

As used herein the terms “removal of material,” “removing material,”“remove” and similar such terms should be given their broadest possiblemeaning, unless expressly stated otherwise. Thus, such terms wouldinclude melting, flowing, vaporization, spalling, chipping, cracking,softening, laser induced break down, ablation, degradation, as well as,combinations and variations of these, and other processes and phenomenathat can occur when directed energy from, for example, a laser beam isdelivered to a material, object or work surface. Such terms wouldfurther include combinations of the forgoing performed with a high powerlaser; and would induce such laser processes and phenomena with theenergy that, for example, a fluid jet may impart to the material to beremoved. Moreover, irrespective of the processes or phenomena takingplace, such terms would include the lessening, opening, cutting,severing or sectioning of the material, object or targeted structure.

As used herein the terms “work piece,” “work surface,” “work area”“target” and similar such terms should be given their broadest possiblemeaning, unless expressly stated otherwise. Thus, such terms wouldinclude any and all types of objects, organisms, coatings, buildups,materials, formations, tubulars, substances or things, and combinationsand variations of these, that are intended to be, or planned to be,struck, e.g., illuminated or contacted, by a high power laser beam.

As used herein, unless expressly stated otherwise, the terms “workover,”“completion” and “workover and completion” and similar such terms shouldbe given their broadest possible meanings and would include activitiesthat place at or near the completion of drilling a well, activities thattake place at or the near the commencement of production from the well,activities that take place on the well when the well is producing oroperating well, activities that take place to reopen or reenter anabandoned or plugged well or branch of a well, and would also includefor example, perforating, cementing, acidizing, pressure testing, theremoval of well debris, removal of plugs, insertion or replacement ofproduction tubing, forming windows in casing to drill or completelateral or branch wellbores, cutting and milling operations in general,insertion of screens, stimulating, cleaning, testing, analyzing andother such activities. These terms would further include applying heat,directed energy, preferably in the form of a high power laser beam toheat, melt, soften, activate, vaporize, disengage, crack, alter,chemically change, cleave, desiccate and combinations and variations ofthese, materials in a well, or other structure, to remove, assist intheir removal, cleanout, condition and combinations and variation ofthese, such materials.

As used herein, unless expressly stated otherwise, the term “flowassurance” should be given its broadest possible meaning, and wouldinclude for example, activities relating to maintaining, assuring,enhancing, restoring, improving, and achieving the flow of materials,such as liquids, gasses, slurries, and mixtures, in a tubular. This termwould cover such activities along the entire stream of commerce; forexample from delivery to and use by a consumer or customer back alongthe chain of commerce to the origins of the material, or its rawmaterial, e.g., the removal or harvesting of the raw material orresource from the earth or a body of water. This term would beapplicable to such activities, for example, in the geothermal,hydrocarbon, oil and natural gas, water, waste treatment, chemical, foodprocessing, biologic and pharmaceutical industries, to name a few. Thisterm would also include the activities that come under the range ofactivities that have been recently used in the oil and natural gasindustries to describe the assurance that hydrocarbons can be broughtout of the earth and delivered to a customer, or end user.

SUMMARY

There has been a long standing need to assure and maintain the flow ofmaterials in tubulars. The present inventions, among other things, solvethese and other needs by providing the articles of manufacture, devicesand processes taught herein.

There is provided a high power laser system for performing laseroperation on a material in a borehole, the system having: a high powerlaser having the capability of providing a laser beam having at leastabout 20 kW of power; a long distance high power transmission cable forproviding the high power laser energy deep within a borehole hole; and,a high power laser tool having a high power laser optic to provide anannular laser beam pattern.

Further, there is provided a high power laser system for performing insitu high power laser processing of a material in a borehole, the systemhaving: a laser capability of providing a laser beam having at leastabout 20 kW of power; a long distance high power transmission cable fortransmitting the high power laser; a high power in situ processing lasertool optically associated with the transmission cable and the laser; thelaser tool positioned in the borehole adjacent an area of likely flowimpediment; and, the high power laser tool having: (i) a high powerlaser optic to provide the laser beam in a laser beam pattern and alonga laser beam path; (ii) a laser flow passage, the flow passageconfigured to, at least in part, operationally influence a flowinghydrocarbons in the borehole; wherein the laser beam path, at least inpart, travels through the laser flow passage, whereby flowinghydrocarbons are capable of being processed by the laser beam deliveredalong the laser beam path in the laser beam pattern.

Additionally, there is provided the high power laser systems and methodsfor performing in situ high power laser processing of materials that mayhave one or more of the following features: wherein the laser tool islocated at least about 1,000 feet from a surface of the borehole;wherein the laser tool is located at least about 2,000 feet from asurface of the borehole; wherein the laser tool is located at leastabout 3,000 feet from a surface of the borehole; wherein the laser toolis located at least about 1,000 feet from a surface of the borehole andthe system has a second high power laser tool having a high power laseroptic to provide the laser beam in a laser beam pattern and along alaser beam path, a laser flow passage, the flow passage configured to,at least in part, operationally influence the flowing hydrocarbons inthe borehole; wherein the laser tool is located at least about 1,000feet from a surface of the borehole and the system has a polishedstinger sub and a sealing member; wherein the laser tool is located atleast about 10,000 feet from a surface of the borehole and the systemhas a polished stinger sub, a sealing member, and a second high powerlaser tool having a high power laser optic to provide the laser beam ina laser beam pattern and along a laser beam path, a laser flow passage,the flow passage configured to, at least in part, operationallyinfluence the flowing hydrocarbons in the borehole and a third highpower laser tool having a high power laser optic to provide the laserbeam in a laser beam pattern and along a laser beam path, a laser flowpassage, the flow passage configured to, at least in part, operationallyinfluence the flowing hydrocarbons in the borehole; wherein hydrocarbonsare flowing in the borehole and the flowing hydrocarbon has at leastabout 0.4 wt % asphaltene; wherein hydrocarbons are flowing in theborehole and wherein the flowing hydrocarbon has at least about 1 wt %asphaltene; wherein hydrocarbons are flowing in the borehole and theflowing hydrocarbon has at least about 1.2 wt % asphaltene; whereinhydrocarbons are flowing in the borehole and the flowing hydrocarbon hasat least about 4 wt % asphaltene; wherein hydrocarbons are flowing inthe borehole and the flowing hydrocarbon has at least about 6 wt %asphaltene; wherein hydrocarbons are flowing in the borehole and theflowing hydrocarbon has at least about 10 wt % asphaltene; wherein thesystem is capable of increasing the S-value of the flowing hydrocarbonby at about 0.05; wherein the system is capable of increasing theS-value of the flowing hydrocarbon by at about 0.01; wherein the systemis capable of increasing the S-value of the flowing hydrocarbon by atabout 0.02; wherein the system is capable of increasing the S-value ofthe flowing hydrocarbon by at about 1; and wherein the system is capableof increasing the S-value of the flowing hydrocarbon by at about 2.

Yet further, there is provided a high power laser system for performingin situ high power laser processing of flowing material in a borehole,the system having: a high power laser capable of delivering a high powerlaser beam; a high power in situ processing laser tool opticallyassociated with the transmission cable and positioned in the borehole;and, the high power laser tool having a high power laser optic toprovide the laser beam in a laser beam pattern and along a laser beampath, a laser flow passage, the flow passage configured to, at least inpart, channel a flowing hydrocarbons in the borehole; wherein the laserbeam path, at least in part, travels through the flow passage, wherebythe flowing hydrocarbons are capable of being processed by the laserbeam delivered along the laser beam path in the laser beam pattern.

Further, there is provided a high power laser system for performing insitu high power laser processing of a material in a borehole, the systemhaving: a high power laser system associated with a borehole, theborehole producing flowing hydrocarbons; the high power laser systemhaving the capability of providing a laser beam having at least about 10kW of power; the high power laser system having a long distance highpower transmission cable for transmitting the high power laser; a highpower in situ processing laser tool optically associated with thetransmission cable and positioned in the borehole adjacent an area ofthe borehole having a flow impediment material; and, the high powerlaser tool having a high power laser optic to provide the laser beam ina laser beam pattern and along a laser beam path, the laser beam pathintersecting a borehole sidewall; wherein the laser beam path, at leastin part, travels through a flow impediment material, whereby the flowimpediment material is removed without damaging the sidewall of theborehole.

Moreover, there is provided the high power laser systems and methods forperforming in situ high power laser processing of materials that mayhave one or more of the following features: wherein the laser tool islocated at least about 5,000 feet from a surface of the borehole;wherein the flow impediment material has a precipitate; wherein the flowimpediment material has an asphaltene; wherein the flow impedimentmaterial has Barium Sulfate; wherein the flow impediment material has ametal organic compound; wherein the flow impediment material has a gashydrate; wherein the flow impediment material has a clathrate hydrate;wherein the flow impediment material has a wax; and wherein the flowimpediment material has a solid.

Still additionally, there is provide a high power laser system forperforming in situ high power laser processing of a material in aborehole, the system having: a long distance high power transmissioncable for transmitting the high power laser; a high power in situprocessing laser tool optically associated with the transmission cableand positioned in the borehole; and, the high power laser tool having ahigh power laser optic to provide the laser beam in a laser beam patternand along a laser beam path, the laser beam path intersecting a boreholesidewall; wherein the laser beam path, at least in part, travels througha flow impediment material, whereby the flow impediment material isremoved without damaging the sidewall of the borehole.

Moreover, there is provided the high power laser systems and methods forperforming in situ high power laser processing of materials that mayhave one or more of the following features: wherein the flow impedimentmaterial has at least about a 10% blockage of a passage in the borehole;wherein the flow impediment material has at least about a 20% blockageof a passage in the borehole; wherein the flow impediment material hasat least about a 50% blockage of a passage in the borehole; wherein theflow impediment material has at least about a 90% blockage of a passagein the borehole; wherein the flow impediment material has at least abouta 10% blockage of a passage in the borehole and the flow impedimentmaterial is one of a precipitate, a solid, a paraffins, a wax, anasphaltene, a gas hydrate, a scale, Barium Sulfate, and calciumcarbonate; wherein the flow impediment material has at least about a 20%blockage of a passage in the borehole and the flow impediment materialis a material selected from a precipitate, a solid, a paraffins, a wax,an asphaltene, a gas hydrate, a scale, Barium Sulfate, and calciumcarbonate; wherein the flow impediment material has at least about a 75%blockage of a passage in the borehole and the flow impediment materialis one of a precipitate, a solid, a paraffins, a wax, an asphaltene, agas hydrate, a scale, Barium Sulfate, and calcium carbonate.

Yet further, there is provided the high power laser systems and methodsfor performing in situ high power laser processing of materials that mayhave one or more of the following features: wherein the laser beampattern is annular; wherein the laser beam pattern is scanned; andwherein the laser beam pattern is one of a radially expanding conicalbeam pattern and a collimated circular beam pattern.

In addition, there is provided a method of in situ high power laserprocessing of flowing material in a borehole, the method having:associating a high power laser system with a borehole, the boreholeproducing flowing hydrocarbons; the high power laser system having thecapability of providing a laser beam having at least about 10 kW ofpower; the high power laser system having a long distance high powertransmission cable for transmitting the high power laser; a high powerin situ processing laser tool optically associated with the transmissioncable and positioned in the borehole adjacent an area of likely flowimpediment; and, the high power laser tool having a high power laseroptic to provide the laser beam in a laser beam pattern and along alaser beam path, a laser flow passage, the flow passage configured to,at least in part, operationally influence the flowing hydrocarbons inthe borehole; delivering the high power laser beam along the laser beampath wherein the laser beam path, at least in part, travels through theflow passage, whereby the flowing hydrocarbons are processed by thelaser.

Further, there is provided a method of in situ high power laserprocessing of a material in a borehole, the system having: associating ahigh power laser system with a borehole, the borehole producing flowinghydrocarbons; the high power laser system having the capability ofproviding a laser beam having at least about 10 kW of power; the highpower laser system having a long distance high power transmission cablefor transmitting the high power laser; a high power in situ processinglaser tool optically associated with the transmission cable andpositioned in the borehole adjacent an area of the borehole having aflow impediment material; and, the high power laser tool having a highpower laser optic to provide the laser beam in a laser beam pattern andalong a laser beam path, the laser beam path intersecting a boreholeside wall; delivering the laser beam along the laser beam path whereinthe laser beam, at least in part, strikes the flow impediment material,whereby the flow impediment material is lessened.

Still additionally, there is provided a high power laser system forperforming in situ high power laser processing of flowing material in atubular, the system having: a high power laser system associated with atubular, the tubular having a flowing material; the high power lasersystem having the capability of providing a laser beam having at leastabout 5 kW of power; the high power laser system having a long distancehigh power transmission cable for transmitting the high power laser; ahigh power in situ processing laser tool optically associated with thetransmission cable and positioned in the tubular adjacent an area oflikely flow impediment; and, the high power laser tool having a highpower laser optic to provide the laser beam in a laser beam pattern andalong a laser beam path, a laser flow passage, the flow passageconfigured to, at least in part, operationally influence the flowingmaterial in the tubular; wherein the laser beam path, at least in part,travels through the flow passage, whereby the flowing material isprocessed by the laser beam.

Moreover there is provided the high power laser systems and methods forperforming in situ high power laser processing of materials associatedwith or in a tubular that may have one or more of the followingfeatures: wherein the tubular is associated with or a part of a boiler;wherein the tubular is associated with or apart of a desalinizationsystem; wherein the tubular is a pipeline; wherein the tubular isassociated with or a part of a chemical processing plant; and whereinthe tubular is associated with or a part of a nuclear power plant.

Further, there is provided a high power laser system for performing insitu high power laser processing of a material in a tubular, the systemhaving: a high power laser system associated with a tubular, the tubularhaving a flowing material; the high power laser system having thecapability of providing a laser beam having at least about 10 kW ofpower; the high power laser system having a long distance high powertransmission cable for transmitting the high power laser; a high powerin situ processing laser tool optically associated with the transmissioncable and positioned in the tubular adjacent an area of the tubularhaving a flow impediment material; and, the high power laser tool havinga high power laser optic to provide the laser beam in a laser beampattern and along a laser beam path, the laser beam path intersectingtubular side wall; delivering a laser beam along the laser beam path,wherein the laser beam path, at least in part, strikes the flowimpediment material, whereby the flow impediment material is lessened.

Additionally, there is provide a method of addressing hydrate formationin subsea structures, including: positioning a submersible assemblyadjacent to a subsea structure; the submersible assembly comprising alaser tool in optical communication with a high power laser; the lasertool delivering a high power laser beam to the subsea structure, whereinthe high power laser beam heats the subsea structure and therebymitigates hydrate formation.

Still further there is provided system and methods having one or more ofthe following features: wherein the subsea structure is only opticallycontacted by the submersible assembly; wherein the subsea structure isnot physically contacted; wherein the subsea structure is comprises acomponent of a deep water offshore hydrocarbon production system;wherein the submersible assembly is an ROV; wherein the subsea structureis selected from the group consisting of a line, a flow line, a linealong the sea floor, a tree, a manifold, a BOP, a riser, devices andequipment; wherein the wavelength of the laser is from about 455 nm toabout 2100 nm; wherein the wavelength is from about 400 nm to about 800nm; and wherein the laser beam is delivered through a laser fluid jet.

Moreover there is provided a method of mitigating hydrate formation insubsea flow lines, equipment, structures or devices in subsea oilfields, including: positioning an ROV, comprising a high power lasertool, near a subsea structure in a subsea oil field; and, heating anarea of the subsea structure with a laser beam delivered from the highpower laser tool; whereby the heating mitigates hydrate formation.

Still further there is provided system and methods having one or more ofthe following features: wherein the subsea structure is heated above atemperature for hydrate formation in the structure; wherein the heatingmaintains the subsea structure at a predetermined temperature; andwherein the predetermined temperature is above a temperature for hydrateformation in the structure; and wherein the hydrate comprises methane.

Yet further, there is provided a method of in situ high power laserprocessing of a material in a tubular, the system having: associating ahigh power laser system with a tubular; the high power laser systemhaving the capability of providing a laser beam having at least about 10kW of power, at least about 20 kW of power and at least about 30 kW ofpower; the high power laser system having a long distance high powertransmission cable for transmitting the high power laser; a high powerin situ processing laser tool optically associated with the transmissioncable and positioned in the tubular adjacent an area of the boreholehaving a flow impediment material; and, the high power laser tool havinga high power laser optic to provide the laser beam in a laser beampattern and along a laser beam path, the laser beam path intersecting atubular side wall; delivering the laser beam along the laser beam pathwherein the laser beam, at least in part, strikes the flow impedimentmaterial, whereby the flow impediment material is lessened.

Still moreover, there is provided a high power laser system forperforming in situ high power laser processing of flowing material in aborehole, the system having: a high power laser system associated with aborehole, the borehole producing flowing hydrocarbons; the high powerlaser system having the capability of providing a laser beam having atleast about 20 kW of power; the high power laser system having a longdistance high power transmission cable for transmitting the high powerlaser; a high power in situ processing laser tool optically associatedwith the transmission cable and positioned in the borehole adjacent anarea of likely flow impediment; and, the high power laser tool having ahigh power laser optic to provide the laser beam in a laser beam patternand along a laser beam path, a laser flow passage, the flow passageconfigured to, at least in part, operationally influence the flowinghydrocarbons in the borehole; wherein the laser beam path, at least inpart, travels through the flow passage, whereby the flowing hydrocarbonsare capable of being processed by the laser beam delivered along thelaser beam path in the laser beam pattern.

Moreover there is provided the high power laser systems and methods forperforming in situ high power laser processing of materials that mayhave one or more of the following features: wherein the laser tool islocated at least about 1,000 feet from a surface of the borehole;wherein the laser tool is located at least about 2,000 feet from asurface of the borehole; wherein the laser tool is located at leastabout 3,000 feet from a surface of the borehole; wherein the laser toolis located at least about 5,000 feet from a surface of the borehole;wherein the laser tool is located at least about 10,000 feet from asurface of the borehole; wherein the system has a polished stinger sub;wherein the system has a sealing member; and wherein the laser tool islocated at least about 15,000 feet from a surface of the borehole.

Yet further there is provided a high power laser system for performingin situ high power laser processing of flowing material in a borehole,the system having: a high power laser system associated with a borehole;the high power laser system having the capability of providing a laserbeam having at least about 20 kW of power; the high power laser systemhaving a long distance high power transmission cable for transmittingthe high power laser; a high power in situ processing laser tooloptically associated with the transmission cable and positioned in theborehole adjacent an area of likely flow impediment; and, the high powerlaser tool having a high power laser optic to provide the laser beam ina laser beam pattern and along a laser beam path, a laser flow passage,the flow passage configured to, at least in part, channel the flowinghydrocarbons in the borehole; wherein the laser beam path, at least inpart, travels through the flow passage, whereby the flowing hydrocarbonsare capable of being processed by the laser beam delivered along thelaser beam path in the laser beam pattern.

Still additionally there is provided a high power laser system andmethod for performing in situ high power laser processing of flowingmaterial in a borehole, the system having: a high power laser systemassociated with a borehole, the borehole producing flowing hydrocarbons;the high power laser system having the capability of providing a laserbeam having at least about 10 kW of power; the high power laser systemhaving a long distance high power transmission cable for transmittingthe high power laser; a high power in situ processing laser tooloptically associated with the transmission cable and positioned in theborehole adjacent an area of likely flow impediment; and, the high powerlaser tool having a high power laser optic to provide the laser beam ina laser beam pattern and along a laser beam path, a laser flow passage,the flow passage configured to, at least in part, operationallyinfluence the flowing hydrocarbons in the borehole; wherein the laserbeam path, at least in part, travels through the flow passage, wherebythe flowing hydrocarbons are capable of being processed by the laserbeam delivered along the laser beam path in the laser beam pattern.

Still moreover there is provided a high power laser system and methodfor performing in situ high power laser processing of flowing materialin a borehole, the system having: a high power laser system associatedwith a borehole, the borehole producing flowing hydrocarbons; the highpower laser system having the capability of providing a laser beamhaving at least about 10 kW of power; the high power laser system havinga long distance high power transmission cable for transmitting the highpower laser; a high power in situ processing laser tool opticallyassociated with the transmission cable and positioned in the boreholeadjacent an area of likely flow impediment; and, the high power lasertool having a high power laser optic to provide the laser beam in alaser beam pattern and along a laser beam path, a laser flow passage,the flow passage configured to, at least in part, channel the flowinghydrocarbons in the borehole; wherein the laser beam path, at least inpart, travels through the flow passage, whereby the flowing hydrocarbonsare capable of being processed by the laser beam delivered along thelaser beam path in the laser beam pattern.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a cross sectional view of an embodiment of a laser tool inaccordance with the present inventions.

FIG. 2 is cross sectional view of an embodiment of a laser tool inaccordance with the present inventions.

FIG. 3 is a perspective view of an embodiment of a laser system inaccordance with the present inventions.

FIG. 4 is a perspective cross sectional view of an embodiment of a lasertool in accordance with the present inventions.

FIG. 5 is a perspective cross sectional view of an embodiment of a lasertool in accordance with the present inventions.

FIG. 6 is a perspective view of an embodiment of a deployment of a lasertool system in a subsea production field in accordance with the presentinventions.

FIGS. 7A and 7B are perspective cross sectional views of an embodimentof a laser tool and process in accordance with the present inventions.

FIGS. 8A, 8B and 8C are perspective cross sectional views of anembodiment of a laser tool and process in accordance with the presentinventions.

FIG. 9 is a schematic of an embodiment of a laser tool optic and laserbeam pattern in accordance with the present inventions.

FIG. 10 is a schematic of an embodiment of a laser tool optic and beampattern in accordance with the present inventions.

FIG. 11 is a cross sectional view of the embodiment of FIG. 10.

FIG. 12 is a schematic of an embodiment of a laser tool optic and beampattern in accordance with the present inventions.

FIGS. 13A and 13B are schematics of an embodiment of a laser tool opticand beam pattern in accordance with the present inventions.

FIGS. 14, 14A and 14B are perspective views of embodiments of laser tooloptics in accordance with the present inventions.

FIGS. 15A to 15C are cross sectional views of an embodiment of a lasertool and process in accordance with the present inventions.

FIGS. 16 and 16A are cross sectional views of an embodiment of a lasertool in accordance with the present inventions.

FIGS. 17 and 17A are cross sectional views of an embodiment of a lasertool in accordance with the present inventions.

FIGS. 18 and 18A are cross sectional views of an embodiment of a lasertool in accordance with the present inventions.

FIG. 18B is a schematic view of the embodiment of FIG. 18 in a tubular.

FIGS. 19A to 19C are perspective cross sectional views of an embodimentof a laser tool and process in accordance with the present inventions.

FIG. 20 is a perspective cross sectional view of an embodiment of alaser tool and process in accordance with the present inventions.

FIGS. 21 to 21A are cross sectional views of an embodiment of a lasertool and process in accordance with the present inventions.

DESCRIPTION OF THE PREFERRED EMBODIMENTS

In general, the systems, tools and methods of the present inventions aredirected to, and provide for, activities such as the cleaning,resurfacing, removal, preventing, managing, cracking, cleaving, melting,altering, changing, phase changing, chemically changing, mitigation andclearing away of unwanted materials (e.g., build-ups, foulings,deposits, corrosion, or other substances) from, at, in, on, or aroundstructures (e.g., a work piece, work area, target area, target surfaceor work surface, including interior surface). Such unwanted materialscould include, by way of example, asphaltenes, rust, corrosion,corrosion by products, precipitates, waxes, degraded or old paints,calcium carbonates, barium sulfates, gas hydrates, clathrate hydrate,degraded or old coatings, paints, NORM (naturally occurring radio activematerials), coatings, waxes, hydrates, microbes, paraffins, residualmaterials, biofilms, tars, sludges, scales and slimes. The presentinventions utilize high power directed energy in novel and uniquemanners to perform such operations and activities.

Generally, directed energy in the form of high power directed energyhaving sufficient power, properties and characteristics, for delivery toand utilization at remote and difficult to access locations may be usedto perform such directed energy operations and activities. Thesedirected energy operations and activities include directed energy flowassurance, which includes directed energy operations and activities to,for example, maintain, assure, enhance, restore, improve, and achievethe flow of materials, such as liquids, gasses, slurries, and mixtures,in articles and structures such as in a tubular, pipe, pipeline, flowline, tunnel, conduit, channel, and production tubing. These directedenergy flow assurance techniques and systems can provide flow assurancefrom start to finish, and any point in between, in a materialsutilization and disposal, including reuse or recycling, after thematerial's initial use. Thus, these directed energy systems, tools andmethods may find application anywhere from the removal of the material,or its source, from the earth, a body water or other source, through anyand all processing and delivery steps until the material reaches and isused by a consumer or customer, and its disposal, recycle or reuse. Thepresent directed energy flow assurance methods, systems and tools areapplicable to, for example, the geothermal, pipeline, waste handling,water, hydrocarbon, oil and natural gas, chemical, food processing, andpharmaceutical industries.

For example, the directed energy may be in the form of high power laserenergy, e.g., a high power laser beam, having sufficient power,properties and characteristics, for delivery to and utilization atremote and difficult to access locations and perform such directedenergy operations and activities. These laser operations and activitiesinclude laser flow assurance, which includes laser operations andactivities to, for example, maintain, assure, enhance, restore, improve,and achieve the flow of materials, such as liquids, gasses, slurries,and mixtures, in articles and structures such as in a tubular, pipe,pipeline, flow line, tunnel, conduit, channel, and production tubing.These laser flow assurance techniques and systems can provide flowassurance from start to finish, and any point in between, in a materialsutilization and disposal, including reuse or recycling, after thematerial's initial use. Thus, these laser systems, tools and methods mayfind application anywhere from the removal of the material, or itssource, from the earth, a body water or other source, through any andall processing and delivery steps until the material reaches and is usedby a consumer or customer, and its disposal, recycle or reuse. Thepresent laser flow assurance methods, systems and tools are applicableto, for example, the geothermal, pipeline, waste handling, water,hydrocarbon, oil and natural gas, chemical, food processing, andpharmaceutical industries.

To illustrate these wide and varying systems, tools, methods, techniquesand applications, this specification will turn to laser flow assurancein oil and natural gas applications. It being noted that these andvariations of these embodiments, as well as others, may be used in otherindustries and in other applications, e.g., geothermal, desalinizationunits, turbines, boilers, pharmaceutical, and chemical, withoutdeparting from the spirit of the present inventions. And thus, theseillustrative oil and natural gas flow assurance embodiments andteachings do not, and should not be used to limit the scope of thepresent inventions.

During oil and natural gas exploration, production, collection,transportation and processing (e.g., refining), there are many variedconditions that can occur in related equipment and structures thatdisrupts, fouls, slows down, prevents, or otherwise impedes the flow ofhydrocarbons, e.g., oil, crude oil and natural gas. These conditions candevelop gradually over time, develop slowly and then accelerate, ordevelop very quickly and in either anticipated or unanticipated manners.These condition have the potential to greatly reduce production or otheractivities, if not halt it entirely. They can result in blockages thatcan cause substantial damage to existing equipment and piping resultingin this equipment having to be removed and replaced, with the associatedcosts and loss of production time. These blockages may further breakfree on their own, or during remediation steps, and travel down streamstriking and damages other equipment, as well as forming new flowimpediments. In some situations the blockages and flow impedingconditions may be so sever as to require abandonment of a well. Theseflow impeding conditions may be temperature dependent, flow ratedependent, pressure dependent, hydrocarbon composition dependent, andvariations and combinations of these, among other contributing factors,which factors are known to those of skill in the oil and gas arts.

In general, laser flow assurance can be conducted by delivering a highpower laser beam preferably having a predetermined energy, pattern andbeam characteristics to a predetermined area in a well, relatedequipment, or other equipment, to perform a laser operation that:changes, alters or disrupts one or more of the contributing factors tolessen, or drive conditions away from, the formation of flowimpediments; ablates, melts, spalls, vaporizes, softens, solubilizes,and combinations and variations of these, a flow impediment; enhances,causes or drives the action of a cleaning chemical or solvent to removea flow impediment, lessen the likelihood of formation of a flowimpediment, or both; and combinations and variations of these. The laserbeam can be delivered as a continuous wave (“CW”) or pulsed laser andcombinations and variations of these.

The laser beam can be delivered to the work area, as a prophylacticmeasure to prevent, lessen, manage, or minimize the formation of flowimpediments. In this prophylactic application, the laser beam (whetherCW or pulsed) can be fired continuously, at set times and for setdurations, or it can be fired when well sensors or tests indicate thatconditions for creating flow impediments are developing, or that flowhas begun to slow.

For active, prophylactic or both, flow assurance measures, the laserbeam delivery apparatus can be moved into the well and positioned at thedesired location by for example a mobile laser unit, for example andpreferably of the type disclosed and taught in US Patent ApplicationPublication No. 2012/0068086, the entire disclosure of which isincorporated herein by reference. The laser beam delivery apparatus canalso be prepositioned in the well or equipment at various locationswhere there is a high or predictable likelihood that a flow impedimentmay form, or where there is a high or predictable likelihood that thelaser can function in a prophylactic manner, and combinations andvariations of these. Thus, the laser beam delivery apparatus can bedistributed throughout a well, related equipment, other equipment orprocess equipment at predetermined locations. For such laser flowassurance systems, the laser beam delivery apparatus can be: integralwith well tubulars or structures, e.g., casing or production tubing, andrelated equipment; it can be prepositioned during drilling or casing ofthe well; it can be positioned as the well is being completed; it can bepositioned after completion; and combinations and variations of these.In other applications, such as processing applications, the lasersystems and laser delivery apparatus can be similarly positioned ordistributed throughout the equipment or infrastructure at strategic,needed or predetermined locations.

Generally, the duration of laser firing (e.g., laser beam propagation tothe work area) will exceed the duration (e.g., pulse width) of a singlepulse for a pulsed laser; for a CW laser this is not pertinent as bothdurations are the same. Thus, and typically, during the firing of apulsed laser for a laser flow assurance operation, there may behundreds, thousands, and hundreds-of-thousands of individual pulsesdelivered. However, it should be noted that if the duration of firing isequal to the pulse width, than these two times may be equal.

Laser flow assurance may be conduced during any phase of operation ofhydrocarbon production, refining, transport and use. Thus, for example,Laser flow assurance may be conducted: on live wells while they areflowing or producing; on evacuated areas of producing wells that havebeen sealed (e.g., with a plug); on shut in wells; on plugged wells; onabandoned wells; on horizontal wells; on the junction of horizontal andparent wells; on subsea collection equipment; on subsea productionequipment; on well heads; on areas deep within a well; on perforationsand perforation areas; on screens; on production areas of a well; on payzones of a well; on areas of a well near or at the sea floor; on areasof a well deep beneath the seafloor; on areas of a well below thepermafrost zone; on areas of a well near or in the permafrost zone; onareas of a well near or at the top of a marine riser; on areas of a wellat or near the bottom of a marine rise; on subsea production tubing; onareas of a well at or near the top of the well; on areas of a well at ornear a rig floor; on areas of a well at or near the surface of a body ofwater; on collecting piping, and on transferring piping. It beingunderstood that “on” as used herein, unless expressly providedotherwise, is used in a broad, expansive, and non-limiting manner. Thus,the phrase “on” a tubular would include, for example, within thetubular, in the tubular, adjacent the tubular, at the tubular, at aninner surface of the tubular, and at an outer surface of the tubular.

In embodiments of the present inventions high powered lasers can be usedto prevent or remove deposits from wells, pipelines and other pressurecontainment equipment. Laser flow assurance systems can deliver highpower laser beams having greater than about 5 kW, greater than about 10kW, greater than about 15 kW, greater than about 20 kW, greater thanabout 40 kW, and greater to target areas or locations near the surface,one the surface, above the surface, or deep within a well. As used inthis specification, unless expressly provided otherwise, the term“about” would include reasonable measuring, analysis and experimentalerrors, and would include up to ranges of plus or minus 10%.

The fouling, e.g., impairment of flow, of conduits, equipment andtubulars used in obtaining, refining and delivering hydrocarbons, amongother reasons, may occur from the deposition of heavy organic molecules.The heavier organic molecules or compounds that may deposit out ahydrocarbon stream, e.g., a petroleum fluid and crude oil, wouldincluded asphaltenes, asphaltogenic acids, diamondoids, paraffins,waxes, and potentially resins. These compounds separate out from the oilfor various reasons and under various conditions and form depositions oncomponents, which can foul the reservoir, the well, pipelines, and oilproduction and processing equipment and facilities. Asphaltene is one ofthe more problematic of these fouling compounds and can generally beviewed as acting like a glue or mortar clogging up the flow channels ofa system. Among other reasons, mercaptans and organometallics candeposit because of dissociation and solubility effects, as well as,attachment to surfaces. Among other reasons, asphaltenese andasphaltogenic acids deposit because of variations in temperature,pressure, pH, composition of the flow (e.g., mixing of different crudeoils), flow regime, surface effects, and electro-kinetic phenomena.

Gas hydrates, e.g., clathrate hydrates, (including methane clathrate ormethane hydrate) from when water is present with a gas, e.g., methaneand the pressure and temperature conditions become such that an icecrystalline structure forms around a methane molecule. Gas hydrates havethe ability to severely restrict flow, to break free and damagedownstream equipment, to reform at down stream locations and thus, priorto the present inventions, have proven to be very problematic, difficultto address and costly to hydrocarbon production.

Additionally, scales such a Barium Sulfate, calcium carbonate and othertype of inorganic, and metal organic compounds and salts deposit andcreate flow impairments. These scales are generally characterized byvery low, if no, solubility in water. Typically, Barium Sulfate is amajor constituent of scales that are found in oil and gas productionsystems and equipment. These scales are very difficult to remove and atsome points they can become so entrenched that, prior to the presentinventions, they could only be removed by mechanical milling. Such scalebuild up could cover tens, hundreds and thousands of feet of piping.They may form, and be quite problematic, at perforation areas and atscreens.

Generally, a high power laser beam can be directed to a flow impedingdeposit and the deposit can be removed by the laser energies interactionwith the deposit. Thus, the wavelength of the laser beam can be suchthat it is highly absorbed by a bond, or bonds in the deposit, or morepreferably the material causing the deposit, and in this way themolecular weight of the material, or the size of an agglomeration of thematerial, is reduced to a point where it will be carried away by, e.g.,solubilized by, or dispersed in, the flow of the hydrocarbon, e.g., thecrude oil. In performing such laser operations, the wavelength can beselected to have much greater absorption for the targeted problematicmaterials and lower absorption for the remaining components of thehydrocarbon flow. The high power laser energy may also be directed on tothe deposition gradually melting it and removing it as an obstruction,such as for example with a paraffin blockage or a hydrate blockage. Thehigh power laser energy may also be used to spall, thermally crack, orotherwise fracture and weaken the blockage or build up to the extentthat is can be carried away by the flow of the hydrocarbon or morereadily acted upon by other treatment chemicals or regimes. Generally,in selecting the laser delivery head and the wave length of the laserbeam, the ability to keep the optics clean and free of debris and tohave the laser beam path, along which the laser beam travels after beinglaunched from the optics, in good optical communication with the targetarea, surface or material, e.g., the build up, should preferably be afactor, and more preferably is an important consideration.

Thus, generally, in an embodiment of a preventative technique, the laserenergy can be used to alter or “crack” long chain (i.e., high molecularweight) hydrocarbon materials into shorter chain (i.e., lower molecularweight) materials that are less likely to, or will not, impeded the flowof the hydrocarbons from the well, e.g., the shorter chain moleculeswill not build up and plug the pipes. In many situations these longerchain hydrocarbons, such as asphaltenes, will only cause an impedimentto flow under certain conditions. For example, if certain temperaturesand pressures are present the asphaltenes can come out of the crude oil,deposit on the inner surface of the well, e.g., the production tubing,and form a blockage in the well, which blockage can severely impedeflow, if not stop it all together. Such asphaltene deposits can be overmay feet of tubing in the well, from 10 feet, to hundreds of feet, topotentially thousands of feet.

Hydrocarbon product with high asphaltene content can create restrictionsor blockage of flow paths in wells, pipelines and production equipment,manifest as deposits on the walls of the transport components, initiatedby temperature changes during the transport process.

Asphaltenes are a characterization or group of compounds that covers arange of carbon-based compounds found in hydrocarbon resources such ascrude oil and coal. In general, they are organic materials havingaromatic and naphthenic ring compounds containing nitrogen, sulfur andoxygen molecules. Asphaltenes are soluble in carbon disulfide; but areinsoluble in lighter alkanes, such as n-pentane and n-heptane. Whenpresent in oil, Asphaltenes can exist as a colloidal suspension, or adispersion, stabilized by resin molecules, which can be aromatic ringsystems, that are present in the oil. The stability of asphaltene in theoil depends on the ratio of resin to asphaltene molecules, as well as,the quantity of the resin that is present.

Asphaltene precipitates, disassociates or comes out of the suspension ordispersion, as a result of changes in conditions, such as, pressuredrop, shear (turbulent flow), acids, solution carbon dioxide, injectedcondensate, mixing of incompatible crude oils and combinations andvarious of these and other conditions that weaken or destroy thestability of the asphaltene dispersion in the oil. This coming out ofthe oil, can cause substantial harm to the production equipment and theability of the well to produce oil, including a complete stoppage of allflow.

In addition to hydrogen and carbon, Asphaltenes general may containoxygen, nitrogen, sulfur and trace amounts of metals, such as vanadiumand nickel. In general, asphaltenes may have a C:H ratio in the range ofabout 0.9 to about 1.5, and more typically have been reported at about1:1.2, and typically have been reported to have molecular weights in therange of about 1,000 Da (Daltons) to about 2,000,000 Da. However, thereis a debate as to whether these molecules actually have a weight ofabout 400-1,500 Da (or potentially even less) but aggregate into largerstructures (which are not bonded, and so are technically not a singlemolecule). Regardless of the outcome of this debate, it is these largestructures in the 1,000-2,000,000 Da range that cause flow assuranceproblems, and which the present inventions, among other things, seek toaddress. Asphaltenes can have a structure that can be viewed as having acenter of stacked, flat sheets of condensed (joined) aromatic ringslinked at their edges by chains of alipathic and/or naphthenic-aromaticring systems. Asphaltenes may aggregate or agglomerate giving rise tocompounds or structure of much higher molecular weight, and more complexforms. By way of example, it is believed that an Asphaltene moleculecould be on the order of about 1.5 nm in size; a nanoaggregate on theorder of about 2-3 nm in size, and a cluster on the order of about 4-6nm in size.

Further, and generally, asphaltenes may be defined as a family ofcompounds based on their solubility, which is also the case for resins.Generally, asphaltenes are soluble in an aromatic solvent (toluene) andnot in a paraffinic one (n-heptane).

The resin in crude oil, that keeps the Asphaltenes from depositing,e.g., contributes to the Asphaltenes remaining in solution or otherwisedispersed within the oil, are much smaller molecules and are on therange of about 78 to 1,000 Da.

The relatively large size of the Asphaltenes when compared to othercomponents typically found in hydrocarbon production, e.g., crude oil,and due to its size and composition, make the asphaltenes reactive todirect exposure to the energy of a high powered laser beam.

The laser delivery head of a laser flow assurance system can be deployedinto a flow of hydrocarbon production and be used to project a highpowered laser beam into the flow of production (i.e., in situ), alteringat a molecular level the composition of the product to either mitigateor eliminate the potential for deposition of the asphaltene oncomponents, and in particular, on downstream components. In general, anembodiment of a system for in situ treatment of product can have:surface equipment, e.g., above the ground or surface of a body of water;deployment equipment, e.g., an umbilical and an advancement andretrieval device such as a spool, kreel or reel; and down holecomponents, e.g., a laser treatment assembly or device. The deploymentdevice connects the laser and other surface equipment, such aselectrical, control, data acquisition, and operating fluids, with thedown hole components; and is used to advance, e.g., lower and raise thedown hole components, to the work area, e.g., the location where thelaser operation is to take place. The surface equipment and deploymentequipment may be of the types disclosed and taught in US PatentApplication Publication Nos. 2012/0068086, 2012/0248078, 2010/0044103,2010/0215326, 2010/0044106, 2012/0020631, and 2013/0266031, the entiredisclosures of each of which are incorporated herein by reference.

An embodiment of an in situ laser flow assurance system is shown anddescribed in FIG. 1. A laser treatment assembly 100 is shown deployed ina producing well 101. The laser treatment assembly 100 is deployed inthe well 101 by primary umbilical 103. The well 101 has a perforationarea 104 into which hydrocarbon product (also referred to herein asproduct), e.g., crude oil, flows into the well and up to the surface.The laser treatment assembly has a distribution sub 105. Thedistribution sub 105 is connected to the primary umbilical 103 and anout flow section 106, e.g., a section of perforated deployment tubing.The out flow section 106 is connected by way of deployment tubingsection 107, to a first laser module 108. The first laser module 108 isconnected by way of deployment tubing 109 to a second laser module 110.Laser module 110 is connected by way of deployment tubing 111, to athird laser module 112. Laser module 112 is connected to a flow inletsection 113. The in flow section 113 has a polished stinger sub 114 thathas a sealing member, e.g., a packer 115, associated with it. The lasertreatment assembly 100 has an internal processing flow channel 116 thatpasses through, e.g., connects the flow inlet section 113, the lasermodules 112, 110, 108 and the out flow section 106.

In operation the laser treatment assembly 100 is lowered into the well101 to a position just down stream from, e.g., in FIG. 1 just above, theperforation area 104 where the product is flowing into the well from theformation. (It should be noted that although FIG. 1 shows an essentiallyvertical well, this assembly and other embodiments of the presentinventions can be used in wells other than vertical wells, such as sidetracks, horizontally drilled wells, and well of other angles,orientations and configurations.) The packer 115 is set, forming a sealagainst the inner surface of the well 101 and the outer surface of thepolished stinger sub 114. Once sealed the flow of the product from theformation, as shown by arrows 117 flows into the flow inlet section 113(in this configuration all of the flow from the formation) entering intothe polished stinger sub 114 and flowing up (as shown in FIG. 1) theinternal flow channel 116, as represented by arrow 118. In this mannerall of the flow of product from the well is carried by the internal flowchannel 116 from the in flow section 113 to the third laser module 112,where it is laser processed, then to the second laser module 110, whereit is further laser processes, and to the first laser module 108, whereit is further laser, after which the laser processed product is returnedto the well by the out flow section 106, as shown by arrows 119.

Using analytic techniques the percentage of asphaltenes to resins, andthe relative ratios of these two components of a crude oil and bedetermined. SARA-separation is an example of one type of analysis thatcan be used to make these determinations. In SARA-separation analysisthe crude is characterized into four groupings: saturates; aromatics;resins; and asphaltenes. ASTM standards relating to this analysis arefor example ASTM D4124-09, ASTM D3279-07, and ASTM D6560-12. Othertechniques for determining the resin:asphaltene ratio and percentagesmay also be employed. For example these techniques are discussed in N.Aske, Characterization of Crude Oil Components, Asphaltene Aggregationand Emulsion Stability by means of Near Infrared Spectroscopy andMultivariate Analysis (Thesis, Dept. of Chem., Norwegian University ofScience and Technology Trondheim, 2002) (hereinafter “Aske,Characterization of Crude”), A Hammami, et al., Asphaltenic Crude OilCharacterization: An Experimental Investigation of the Effect of Resinson the Stability of Asphaltenes, Petroleum Science and Technology, Vol.16, Issue 3-4, pages 227-249 (1998), S. Andersen, Petroleum Resins:Separation, Character, and Role in Petroleum, Petroleum Science andTechnology, Vol. 19, Issue 1-2, pages 1-34 (2001), the entire disclosureof each of which are incorporated herein by reference.

The following table provides examples of likely values for asphalteneand resin contents of crudes, and examples of likely changed content ofthese crudes from a laser cracking treatment.

Relative % Second Asphaltene to First Laser Laser Third Laser wt % Resin= Process¹ Process² Process³ wt % asphaltene A/(A + R) * 100 (“% wt % wt% wt % resin (R) (A) AR”) asph. % AR asph. % AR asph. % AR 15.2 0.4 2.6%0.3 2.2% 0.3 2.0% 0.3 1.7% 14.2 0.3 2.1% 0.3 1.8% 0.3 1.6% 0.2 1.4% 20.42.1 9.3% 1.8 8.0% 1.8 7.4% 1.7 6.5% 12.2 1.5 10.9% 1.3 9.5% 1.3 8.7% 1.27.6% 16.0 1.4 8.0% 1.2 6.9% 1.2 6.3% 1.1 5.6% 24.5 3.5 12.5% 3.0 10.8%3.0 9.9% 2.8 8.8% 3.6 10.4 74.3% 8.8 71.1% 8.8 69.1% 8.3 66.0% 4.3 3.444.2% 2.9 40.2% 2.9 37.9% 2.7 34.7% 19.9 12.4 38.4% 10.5 34.6% 10.532.5% 9.9 29.5% 15.2 6.6 30.3% 5.6 27.0% 5.6 25.1% 5.3 22.6% 14.2 12.346.4% 10.5 42.4% 10.5 40.1% 9.8 36.8% 20.4 12.4 37.8% 10.5 34.1% 10.532.0% 9.9 29.0% 12.2 8.6 41.3% 7.3 37.5% 7.3 35.3% 6.9 32.2% 16.0 5.023.8% 4.3 21.0% 4.3 19.5% 4.0 17.4% 24.5 13.0 34.7% 11.1 31.1% 11.129.1% 10.4 26.3% 3.6 1.5 29.4% 1.3 26.2% 1.3 24.4% 1.2 21.9% 4.3 5.556.1% 4.7 52.1% 4.7 49.7% 4.4 46.2% 19.9 3.4 14.6% 2.9 12.7% 2.9 11.7%2.7 10.3% 9.2 9.3 50.3% 7.9 46.2% 7.9 43.9% 7.4 40.5% ¹15% reduction inAsphaltenes ²15% reduction in Asphaltenes, 10% increase in resin ³20%reduction in Asphaltenes, 19% increase in resin

Laser in situ processing of crude oil reduces the relative amount ofasphaltenes present, to increase the relative amount of resin present,and combinations and variation of both, to lessen, reduce or eliminatethe deposition of asphaltene containing deposits. Thus, laser in situprocessing can: reduce the amount of asphaltenes in the crude oil by atleast about 5% (relative % change, e.g., 5% of the originalasphaltenes), by at last about 10%, by at least about 25%, by at leastabout 50% and more; increase the amount of resins in the crude oil byabout 1% or more, by about 5% or more, by about 10% or more, by about15% or more and by about 25% or more; a decrease in the relativepercentage asphaltene to resin value

$\left. {\frac{{Aslphaltene}\mspace{14mu} {wt}\mspace{14mu} \% \mspace{14mu} {of}\mspace{14mu} {crude}}{\left( {{{Aslphatene}\mspace{14mu} {wt}\mspace{14mu} \% \mspace{14mu} {of}\mspace{14mu} {crude}} + {{Resin}\mspace{14mu} {wt}\mspace{14mu} \% \mspace{14mu} {of}\mspace{14mu} {crude}}} \right)} \times 100} \right)$

by at least about 0.1 percentage points, by at least about 0.2percentage points, by at least about 0.5 percentage points, by at leastabout 1 percentage points, by at least about 2, percentage points, by atleast about 5 percentage points, by at least about 10 percentage points,by at least about 15 percentage points, and more; and combinations andvariations of these.

Further, and in particular, for several reasons laser processing has theability to increase the stability of the asphaltenes in the oil, thuspreventing, greatly reducing, or reducing the likelihood that they willprecipitate out of the oil. Thus, the laser processing can provide anincrease in S-value (S-value as determined by ASTM D157-09), andpreferably an increase of at least about 0.05, about 0.1, about 0.15,about 0.2 and greater.

In the embodiment of FIG. 1 the three laser modules 108, 110, 112 areevenly spaced, i.e., the length of deployment tubing 111 and deploymenttubing 109 are essentially the same. In this embodiment the lasermodules 108, 110, 112 are also serially configured, i.e., the flow fromthe first proceeds to the second and so one. It should be understoodthat that the spacing between the modules may be different, and thatmore or fewer modules may be used in a laser treatment assembly.Additionally, the modules may be arranged such that some or all of theirflow paths are in parallel. If configured in parallel, more than onemodule may see, e.g., process, unprocessed product, i.e., product thathas not been laser treated, exposed to the laser beam. For example, anddepending upon flow rate, down hole conditions, and characteristics ofthe hydrocarbon product flowing from the formation, two modules may beused to process the product flowing from the formation (unprocessedproduct, crude) and the flow of laser processed product from these twomodules combined to a third laser module, with the now twice-processedproduct from the third laser module flowing to a fourth laser module.Other configurations of modules may be used, for example two parallelflow configurations of three serially connected modules each. While theflow may be parallel, the actual location of the modules in the lasertreatment assembly may be stacked, e.g., positioned one after the otheralong the longitudinal axis of the assembly. Additionally, the modulesmay be operated simultaneously, or on different, varied, but preferablepredetermined and coordinated duty cycles.

Turning back to the embodiment of FIG. 1, the primary umbilical 103contains three stainless steel umbilicals, 120, 121, 122, each having ahigh power optical fiber, and fluid communications line for a lasermodule, these umbilicals may also have additional lines for data andcontrol information and for electric power associated with them. Thestainless steel umbilicals 120, 121, 122 leave the distribution sub 105and travel down the exterior of the tubing joints to each to theirrespective laser module: umbilical 120 to module 108; umbilical 121 tomodule 110; and umbilical 122 to module 112. It being understood thatthe individual umbilical and fiber could originate at the distributionsub, or could extend within the primary umbilical to the surface. Acontrol line for the packer 115 may be associated with umbilical 122 orit may be separately run to the packer 115.

An embodiment of a laser module that may be used in a laser treatmentassembly is shown and described in FIG. 2. The laser module 208 isattached to deployment tubing 206. Stainless steel umbilical 220 entersinto the deployment tubing 206 through opening 230 in tubing 206. Inthis manner umbilical 220 passes from outside the deployment tubing 206(in the annular space between the tubing 206 and the well) to inside thedeployment tubing 206, and into the internal flow channel 216. Thestainless steel umbilical 220 has an optical fiber 232 enclosed in ametal tube 231 (“FIMT”). The stainless steel umbilical 220 hasassociated with it an electric conductor 233. The FIMT 232, 231terminates at a high power optical connector 234 (which for example maybe of the type disclosed and taught in U.S. patent Ser. No. 13/486,795,the entire disclosure of which is incorporated herein by reference),which launches the laser beam along a laser beam path into the opticspackage 235, having an optics assembly having for example beam shapingand characterizing optics such as a collimator and a focusing lens. Thelaser beam 236 exits, i.e., is launched, propagate, fired from, theoptics package 235 and travels along laser beam path 237 in producttreatment area 239. The laser beam 236 is configured to have apredetermined laser beam pattern 238, which pattern is provided by theoptical assembly.

The laser beam pattern 238, and the energy that this pattern delivers tothe hydrocarbon product as that product flows through the treatment area239, is determined based upon several factors, such as, the flow rate ofthe product, the transitivity of the product for the selected wavelengthof the laser beam, the power of the laser beam, e.g., kW, the totalnumber of modules that are going to be deployed, the desired end pointcharacterization of the product (e.g., amount of asphaltene reduction toreach acceptable limits to avoid impeding flow), the power density ofthe laser beam, e.g., kW/cm², the nature of the asphaltenes or otherlarger molecules that are to be changed by the laser treatment process,as well as the relationship of the module to any other modules that maybe present in the laser treatment assembly, or assemblies.

Additionally, care should be taken to configure the treatment area 239and optics package 235 to minimize and preferably prevent the laserlaunch face, e.g., a window, of the optics package 235 from becomingcontaminated with hydrocarbons, dirt, debris or other materials thatcould cause rapid heating from the laser beam and the potential failureof the optics package and surrounding structures. For example, a gas,e.g., air, nitrogen, or inert gas, or a fluid, e.g., water, oil, thathas good transmissivity for the laser beam wavelength may be dischargedand used to keep launch face clean. Additionally a solvent of otherchemical to assist in the laser treatment process may be injected atthis point. Such treatment fluids, if having acceptable, and preferablylow, absorptivity for the wavelength of the laser may be used to keepthe launch face clean.

The distal end of the optics package 235 and the treatment area 239 arehoused by a module body 240. Temperature sensor 241, as well as othersensors or monitoring devices may be associated with the treatment area239, or the flow channel either downstream, upstream, or both from thetreatment area 239. There is also a section of the stainless steelumbilical 221 for an upstream laser module (not shown in FIG. 2, andwhich would be below module 208 in the orientation of FIG. 2).

As hydrocarbon product flows downstream, (upward as oriented on FIG. 2)it moves along flow channel 216 and enters the treatment area, where itpasses through the laser beam pattern 238, in this configuration theoperable area of the laser beam pattern 238 extends out to the innersurface of the flow channel. Other configurations of the laser pattern,with respect to the shape of the flow channel in the treatment area arecontemplated. Thus, the laser beam pattern may only treat a portion ofthe hydrocarbon flow, e.g., about 80%, about 70%, about 50% or less,with down stream serially positioned modules doing the same or more.Although this may require more modules positioned serially in the lasertreatment assembly, or more serially positioned laser treatmentassemblies in the well, it could reduce the risk to optics packages byproviding for the removal of laser processed product from the beampattern by the product flow that is moving around the beam pattern.Other configurations and shapes of the flow cavity before, in and afterthe laser treatment area are contemplated.

In general, laser flow assurance modules or assemblies can be lowered into the well or pipeline using a deployment tubing, for example, coiledtubing or wireline, and if needed with a setting component, an isolationsealing component and a latch/unlatch component. Preferably, theumbilical is continuous to surface, with the umbilical sealed at thewellhead. Contained within the umbilical can be the high power laseroptic fiber(s), which can be housed in stainless steel protectivetube(s), the electrical conductor(s), and an area, e.g., a channel, forthe flow of fluid, e.g., liquid or gas, to provide any needed fluid feedto the modules. The umbilical is attached to, e.g., in opticalcommunication with, a source of a high power laser beam, and dependingup the desired requirements and performance features, may also beattached to a source for electrical feed, a source for sending orreceiving data and control information, and a source for providing afluid flow. Thus, the umbilical and surface equipment, systems, may beof the type disclosed and taught by US Patent Application Publications2012/0068086 and 2012/0248078, the entire disclosures of each of whichare incorporated herein by reference.

In an embodiment, the laser module preferably has an outside diameter tofit appropriately within the production tubing or casing of the well, orwithin the pipeline inside diameter if installing into a pipeline. Thesemodules can be connected with deployment tubing joints, with thestainless steel protective tubing housing the optical fiber running tothe outside of the deployment tubing until just above the receivingmodule, at which point the tubing will enter to the interior of thedeployment tubing. Inside the deployment tubing, just above the module,the optical fiber may terminate to a connector, with a finned collimatorfitted with lenses.

In an embodiment a laser fluid, e.g., a liquid or gas that the laserbeam at a predetermined wavelength can be readily transmitted throughwith acceptable losses and heat generation, will fill the umbilicalprotective tubing and be used to keep product and debris from the launchface of an optics package, as well as, potentially to keep the opticsassembly clean and to potentially manage the temperature of the opticsassembly, e.g., cool it. The laser fluid, along with the flowinghydrocarbon product, can be used to dissipate heat from the connector,the optics package, and other components within a laser treatmentassembly. Safety shut down systems may be employed such as the use of atemperature sensor, mounted within the optics package and connected tosurface via an electric conductor. Such system can be used to monitorthe temperature of the optical, or other, components and shut down thelaser should the temperature increase above acceptable levels. Theincreased heat may be a result of decreased well flow, or due to amalfunction of the laser fluid fill within the stainless steel umbilicalprotective tubing or for other reasons. Monitoring, control and safetysystems for high power field laser systems are taught and disclose inthe following US patent applications, publication nos. 2012/0273269,2012/0248078, and 2012/0068086 the entire disclosures of each of whichare incorporated herein by reference.

The total number of modules to be run in to a well may be determined by,among other things, the transmissivity of the flowing product, the flowrate of the product, any change in transmissivity of the product if themodules are in a serial processing configuration, the amount ofasphaltene within the product, the amount of resin within the product,the desired resin to asphaltene ratio that the laser processing is toobtain, and combinations and variation of these.

Deployment of the laser modules can be for example done in a two-stepprocess, with either coiled tubing or a wireline unit setting a packerwithin the tubing, and then a coiled tubing unit used to deploy a moduleassembly or laser treatment assembly. A distribution sub, sitting atopthe assembly can serve as the connection for deployment, as well as thecomponent to gather and distribute the laser fluid used in the processand the fibers for the individual modules. A polished stinger sub can belocated at the bottom of the lowest module and is placed thought thesealed bore on the previously set packer, providing isolation anddirecting the product flow through the modules. At the surface, theumbilical is passed through the wellhead, and the feed fluid/gas, andfibers connected to the source components, and the monitoring devicesconnected. Once the well is allowed the flow and product is through themodules, the fluid/gas and laser are started, and treatment of the flowbegun.

As the produced fluid passes through the module flow path, the laserbeam of a determined power is projected into the fluid, and throughselective absorption, the asphaltenes or other preselected componentsare altered, either in whole, or in part, to reduce or eliminate thepossibility of precipitation within the system. However, it is notedthat applicants do not wish to be bound by any one theory of chemicalinteraction between the laser beam, laser energy and the complexcompositions present in a wellbore. Thus, other processes, such asnon-selective absorption, as well as others, could play a role in somecircumstances in the laser treatment of borehole fluids and materials.

Laser flow assurance may also be utilized in laser remediationoperations, e.g., the removal, opening up, or lessening of flowimpediments or restrictions in wells, related equipment and processingequipment. In general, an embodiment of a system for laser remediationoperations can have: surface equipment, e.g., above the ground orsurface of a body of water; deployment equipment, e.g., an umbilical andan advancement and retrieval device such as a spool, kreel or reel; anddown hole components, e.g., a laser treatment assembly or device. Thedeployment device connects the laser and other surface equipment, suchas electrical, control, data acquisition, and operating fluids, with thedown hole components; and is used to advance, e.g., lower and raise thedown hole components, to the work area, e.g., the location where thelaser operation is to take place. The surface equipment and deploymentequipment may be of the types disclosed and taught in US PatentApplication Publication Nos. 2012/0068086, 2012/0248078, 2010/0044103,2010/0215326, 2010/0044106, 2012/0020631, and 2013/0266031, the entiredisclosures of each of which are incorporated herein by reference.

Turning to FIG. 4 there is shown a perspective schematic view of anembodiment of a laser remediation assembly 400, as deployed withinproduction tubing 401 having a deposit 408 that is impeding the flow ofcrude oil. The assembly 400 is attached to an umbilical 402, e.g.,composite tubing, that has a high power laser fiber and other electricaland fluid support channels associated with it. The assembly 400 has atractor section 402 that can advance and retrieve the tool 400 in thetubing 401, and a motor section 404 that can rotate a lower section ofthe tool, which has a scraper 405, optics package section 406 and alaser head 407. In operation the high power laser beam is transmitted bythe optical fiber to the optics section where the laser beam shaped to apredetermined beam pattern, the laser beam is then launched from thelaser head 407 along a laser beam path 409 and onto the deposit 408. Thelaser head is then rotated, rotating the laser beam, along the innercircumference of the production tubing 401. In this manner the laserbeam removes, and/or weakens the deposit, which if any remains isfurther removed by the scrapper 405. Preferably, very little mechanicalforce will be required for the scraper to remove any remainingblockages, after the initial laser pass, because the laser beam willhave substantially weakened any remaining blockage material. The motorsection, optics section and laser head sections may be of the typestaught and disclosed in US Patent Application Publication Nos.2012/0074110 Ser. Nos. 13/403,509, 13/782,869, and 13/768,149, theentire disclosures of each of which are incorporated herein byreference.

Turning to FIG. 5 there is shown a perspective schematic view of anembodiment of a laser remediation assembly 500, as deployed withinproduction tubing 501 having a deposit 508 that is impeding the flow ofcrude oil. The assembly 500 is attached to an umbilical 502, e.g., awire line, that has a high power laser fiber and other electrical andfluid support channels associated with it. The assembly 500 has acentralizer section 513 that has rollers 514. The rollers preventrotation of the tool when the laser head is rotated, while at the sametime allow the tool to be advanced into the well with minimum friction.The umbilical 502 that can advance and retrieve the tool 500 in theproduction tubing 501, a motor section 504 that can rotate the lowersection of the tool, which has the scraper 505, optics package 506 andthe laser head 507. The optics package and laser head 507 deliver thelaser beam in a planer pattern that contacts the entire inner surface ofthe tubular 501 and the deposits on that surface in a line around theinner circumference. Preferably, very little mechanical force will berequired for the scraper to remove any remaining blockages, after theinitial laser pass, because the laser beam will have substantiallyweakened any remaining blockage material. The motor section, opticssection and laser head sections may be of the types taught and disclosedin US Patent Application Publication Nos. 2012/0074110 Ser. Nos.13/403,509, 13/782,869, and 13/768,149, the entire disclosures of eachof which are incorporated herein by reference.

The embodiments of FIGS. 4 and 5, as well as other embodiments, that arereferred to as laser remediation assemblies or tools, may also becapable of and can be used for other applications, such as, in situcracking and resurfacing. Similarly, embodiments that are referred to aspreventative or prophylactic may also be capable of, and can be use for,other laser applications.

Generally, in doing laser remedial operations it is desirable to havethe well flowing. In this manner as the laser weakens, melts,solubilizes, e.g. effects the material forming the blockage or buildup,this laser affected material can be removed and carried out of the wellby the flowing product. To further assist in the removal of the laseraffected blockage material a laser gas jet may be used. The gas from thelaser jet, in additional to provided a clearer laser beam path for thebeam to reach the surface of the blockage, helps to lift or float theremoved material out of the well. If an isolation zone is to be utilizedat the work area it may be created by isolation members, such as apacker of packers. Laser gas jets and movable isolation zone assembliesand techniques are taught and disclosed in US Patent ApplicationPublication Nos. 2012/0067643 and 2012/0074110, the entire disclosuresof each of which are incorporated herein by reference.

Turning to FIG. 3 there is shown a schematic perspective view of asubsea laser remediation assembly 300. A subsea production tree 301 islocated on the sea floor 302 below the surface (not shown in the figure)of a body of water 303. The tree 301 has a permanent riser assembly 350attached to it. The permanent riser assembly 350 is in a “Y”configuration, with one branch 352 extending vertically to provideintervention access and the other branch 351 providing access for thelaser remediation tool. The branch 351 has a riser isolation valve 304,a riser clamp 305. The laser assembly 300 has a deployment valve 306that is attached to clamp 305 to connect and hold the laser assembly 300in association with riser 350. The laser assembly 300 has a laser tooldeployment housing 307, that forms a cavity 309 in which the laser tool308 is housed. When the valves 306 and 304 are opened the cavity 309 isin fluid communication with the riser branch 351 and the tree 301. Thelaser assembly 300 has a laser container 310 that is sealed forprotection from the sea and contains a high power laser 311, aconveyance reel 312 and a conveyance pack-off 313. The laser container310 can be pressure compensated or at atmospheric pressure. Electricpower, fluids of any laser jet, communication and data links areprovided to the laser assembly 300 by umbilical 314.

Turning to FIG. 6 there is shown a perspective view of a subsea oilfield. A FOSP 600 and a spar platform 601 are located on the surface 612of a body of water 611. These collection platforms 600, 601 are connectto the sea floor oil field equipment by lines 603, 604, and 602, withlines 603 connecting FOSP 600 to manifold 606 on the sea floor 610, withlines 604 connecting FOSP 600 to manifold 605 on sea floor 610, and withlines 602 connection spar 601 to manifold 607 on the sea floor 610. Flowlines 613 connect subsea trees 609 to subsea manifolds 607, 606, 605.Additionally flow lines 613 connect subsea manifold 608 to subseamanifold 607. The laser and riser assembly of the embodiment of FIG. 3can be associated with one, two, three or all of the trees in the subseafield of the embodiment in FIG. 6.

Buildup, fouling and flow impairment of the subsea flow lines 613 can bea problem, if not a significant problem in some subsea fields. Theseflow lines are generally horizontal and typically follow the contour ofthe sea floor. Thus, they may raise and lower with the sea floor, insome field they may be buried beneath the sea floor. Prior to thepresent inventions conventional flow assurance measures were costly,time consuming and did not fully address the flow assurance needs forsuch fields. Thus, a laser-tractor PIG assembly may be used to addressthese needs. The laser-tractor PIG assembly has a high power laserdelivery head, an electric driven tractor, and a laser power converterto convert laser energy into electrical energy to power the tractor.Either a single high power laser fiber, or two laser fibers, one for thepower converter and the other for the laser head, can be used.Additional fibers may also be used. The high power laser fibers form alaser-PIG tail, e.g., an umbilical, which weighs substantially less thana conventional umbilical and metal wire power supply for the tractor,and thus has substantially less drag as the tractor pulls the PIG-tailalong the flow lines on the sea floor. One, some, all and preferably allproblematic flow lines on the sea floor are fitted with laser-PIGlaunchers and receivers. The launchers and receivers allow thelaser-tractor PIG to be launched into a flow line, which is stillflowing product and be recovered from that line after the laser flowassurance operation has been performed. An ROV may be used to positionthe laser-tractor PIG in the launcher and recover it, or the laser PIGmay be pre-positioned in the launchers. Laser PIG, laser PIG launchersand receivers, Laser ROVs, and laser power converters are taught anddisclosed in US Patent Application Publication Nos. 2012/0266803,2012/0273470 and 2012/0255933, the entire disclosures of each of whichare incorporated herein by reference.

Generally embodiments of laser flow systems may be integrated into anembodiment of a “well maintenance” system, with configurations forsurface wellheads and sub-sea wellheads. The surface wellheadconfiguration, can be typically set up for application on a fixed legoffshore platform, and could be an easily manipulated system that wouldallow access to all of the well trees on the platforms with minimaleffort and equipment movement. These tools would be run into the wellson a frequency dictated by historical data, or real time sensing andanalysis, to clean the tubular components of any accumulated deposition.A similar configuration would be used for pipelines running to and froman offshore installation, with the tool passed through the pipe on aschedule to prevent flow assurance issues.

Sub-sea configurations may include a special riser assembly mounted atopthe sub-sea production tree, providing two legs, one for the deploymentof the laser tool, the other to allow access for intervention other thanthe laser tool. An atmospheric chamber houses the laser, the reel forthe conveyance component, the pack-off for the well seal when operatingand the laser tool, and is clamped to the riser assembly by way of aremovable clamp to allow the unit to be transported to the surface formaintenance or repair. The unit will be connected to surface equipmentvia an umbilical, which will provide the power for the unit, themovement of either gas or fluid needed for process, and electricalconductors for remote control of the unit, as well as monitoring.

Laser flow assurance systems may allow for the regular maintenance ofwells with known flow assurance issues without the need for installationof chemical injection systems and without an intervention procedure doneon a call out basis. Interventions are often put off until absolutelyneeded due to cost and logistics, with a constantly diminished flow ofproduct occurring between the interventions. These systems will allow aregular cleaning of the well or pipeline, with little or no loss inproduction.

One of the benefits of some of the embodiments of the present flowassurance systems, tools, techniques and methods is the elimination ofthe need for, and use of, costly and hazardous chemical, boil out, andflushing procedures, many of which require the shutting down ofproduction. These conventional treatments may still be used with laserflow assurance treatments to enhance the flow assurance processes. Thus,the present inventions contemplate the use of laser energy enhancedchemical treatments and additives, which preferably provide asynergistic effect when used with, or as a part of, a laser flowassurance application.

Hydrate plugs form when gas and water are common in a flow system andthe molecules of each combine under certain temperature and pressuresituations to form an ice plug in the system, either restricting orstopping the flow of the product. This restriction or plug will resultin diminished production and typically requires intervention methods tocorrect it. The hydrate plugs may occur downhole in wells, withinpipelines, and in other pressure containment components within aproduction system. Laser flow assurance systems provide for theconveyance of a device that uses a high powered laser energy to applytargeted energy to the plug and melt it, without the need for pumping ofchemicals to melt the plug or milling on the plug with a motor and bitto remove.

Laser flow assurance systems and techniques may also be used for theremoval of chemical scale deposition within wells, which systems may usethe laser alone, or in combination with mechanical means, chemicalmeans, and combinations and variations of these. Some formations producechemicals that, when mixed with or contaminated by produced or injectedwater, will cause deposits to accumulate on the walls of the downholetubulars in wells, and in pipelines transporting the produced product tofacilities. Laser flow assurance systems and techniques can providelaser devices capable of removing these deposits, preferably with no orminimal mechanical assist, lessening the potential of damage tocontainment components and not requiring the use of harsh orenvironmentally unfriendly chemicals.

Laser flow assurance tools, techniques and systems can be used forclearing of plugged perforations by using a downhole laser device.Pressure changes at the well to formation interface can cause theperforations to become restricted or plug with deposits, resulting indiminished production. A laser tool can be used to remove the depositswithin the production casing or liner, and re-open the perforations. Theprocess is possible with or without mechanical assist, allowing theprocess to be done in passing through smaller tubing and removing thedeposits within the perforations done in a larger diameter pipe belowthe tubing. A laser tool is passed through the area of perforations withthe centralizer engaged and keeping the laser head centered within thepipe. As the tool is lowered, the laser head spins, providing 360°coverage of the inside of the tubing/pipe. Within the tool an analyticaldevice can be run as the tool is being lowered and spinning to determinethe amount of deposit on the tubing, integral to the tool, and adjustthe laser power to remove the deposit without risk to the tubing/pipebeneath the deposit. The analysis can also determine when a perforationis being crossed with the beam, and allow the beam to penetrate into theperforation to remove deposits that may be inside of the perforationchannel, e.g., reopening the perforations.

Cutting of tail pipe plugged or restricted by scaling within a wellborecan be performed with a laser flow assurance tool. Often deposits willcollect within production tubing near where the tubing ends, or at thetubing “tail.” This portion of the tubing is typically located below thepacker used to isolate the lower perforated section of the casing orliner from the upper section, directing the fluid of product into theproduction tubing. Often the cutting of the tubing that has been blockedis a better option that attempting to clean, eliminating the affectedpipe and reducing the chance of reoccurrence with a repositioning of theentry point of product in to the production tubing. A laser tool can berun in to the well with either for example, coiled tubing or a wirelinetype of conveyance to the depth of desired cut, centralized and anchoredutilizing the electrically actuated tractor/centralizer assembly, thenthe rotating laser head used to sever the lower section of the tubing.By controlled projection of the beam and the beam properties, the tubingwill be cut without possible damage to the casing behind the tubing.

In general, when dealing with cleaning activities, and by way ofexample, the power of the laser energy that is directed to a surface ofthe workpiece should preferably be such that the foreign substance,e.g., a biofilm, wax, etc., is removed or sterilized, by heating,spalling, cutting, melting, vaporizing, ablating etc., as a result ofthe laser beam impinging upon the foreign substance, but the underlyingstructure or surface is not damaged or adversely affected by the laserbeam. In determining this power, the power of the laser beam, the areaof surface that the laser beam illuminates, and the time that the laserbeam is illuminating that surface area are factors to be balanced.

The parameters of the laser energy delivered to a work area or substratehaving an unwanted material should be selected to provide for theefficient removal, or degradation of the unwanted material, whileminimizing any harm to the substrate. The laser delivery parameters willvary based upon, for example, such factors as: the desired duty cycle;the surface area of the substrate to be cleaned; the composition of thesubstrate; the thickness of the substrate; the opacity of the unwantedmaterial; the composition of the unwanted material; the absorptivityand/or reflectivity of the unwanted material for a particular laserwavelength; the absorptivity and/or reflectivity of the wanted materialfor a particular laser wavelength; the geometry of the laser beam; thelaser power; the removal speed (linear or area); as well as, otherfactors that may be relevant to a particular application. Althoughcontinuous wave and pulsed delivery lasers may be useful in addressingthe issue of unwanted materials in or on structures such as for examplepipelines, or in or on other substrates, pulsed laser have been shown tobe particularly beneficial in some applications and situation. Withoutlimitation to the present teachings and inventions set forth in thisspecification, the following US patents set forth parameters and methodsfor the delivery of laser energy to a substrate to remove unwantedmaterials from the substrate: U.S. Pat. Nos. 5,986,234; RE33,777,4,756,765, 4,368,080, 4,063,063, 5,637,245, 5,643,472, 4,737,628, theentire disclosures of each of which are incorporated herein byreference. It is noted, however, that although providing generalteachings about laser beam parameters and delivery none of thesereferences provided or suggest laser flow assurance, and in particularlaser flow assurance in oil, gas and geothermal energy exploration andproduction, either down stream or up stream.

Turning to FIG. 9 there is shown a schematic of an embodiment of anoptics assembly for use in a laser tool. The optics assembly provides aradially expanding conical beam pattern. Thus, the entire innercircumference of a tubular can be contacted by the laser beam withoutrotating the tool, laser head or optics. An axicon lens 900 is shownpositioned relative to a tubular 903 having an inner surface 904, whichsurface is a work surface to be laser treated. A collimated circularlaser beam shown by ray trace lines 901 enters the axicon 900, travelsthrough the axicon and exits in a beam pattern that initially, at arrow905, is characterized as a Bessel pattern and then becomes an expandingannular pattern, e.g., a hollow cone, arrow 906. The annular patternstrikes the work surface 904 in a ring, or band, shaped pattern 907 thatextend around the entirety of the inner circumference of the tubular.Although shown as a collimated beam entering the axicon, the beam mayalso be diverging or converging, and may have a Gaussian distribution orother distributions.

Turning to FIG. 10 there is shown an embodiment of an optics assembly toprovide a cylindrical beam pattern. A collimated circular laser beamshown by ray trace lines 1000 enters a vaxicon lens 1001 where it isformed into an expanding annular (hollow cone) pattern 1002, whichenters a lens 1003, that shapes the beam into a cylindrical beam 1004. Aplan view cross section for the cylindrical beam 1004 is shown withrespect to a tubular having an inner work surface 1005. The centerlineof the beam and tubular is shown by point 1009. The inner side of thecylindrical beam pattern has a radius shown by arrow 1008, the beampattern has a thickness shown by arrow 1007, and the outer side of thebeam pattern has a radius of the sum of the radius 1007 and thickness1008. The distance from the outer side of the beam pattern to the worksurface 1005, is shown by double arrow 1006. Although shown as acollimated beam entering the vaxicon, the beam may also be diverging orconverging, and may have a Gaussian distribution or other distributions.

As seen in FIG. 11, for this beam pattern, the distance 1006 from theoutside of the cylindrical laser beam pattern to the work surface 1005can set based upon the amount, extend of build up on the work surface,the nature of the laser beams interaction with the build up (for exampleif spallation and thermal fracturing are the primary failure mode thanthe distance should be such to enable the fracturing to reach or otherwise remove the build up material from the work surface), the nature ofthe work surface, (for example preventing it from being damaged by thelaser beam), whether other mechanical or laser processes can be used toremove any remaining build up (for example the tool could be configuredto have a 20 kW, cylindrical beam extending forward in the direction oftravel from a first laser module and a second laser module behind thefirst providing a lower power, e.g., 2 kW ring pattern to remove anymaterial that the cylindrical beam pattern left behind, while at thesame time minimizing the risk that the laser contacting the work surfacecould damage the work surface), and other factors and consideration. Forexample, the distance 1006 from the side wall could be from about ⅛″ toabout 3″, could be from about ½″ to about 2″, could be less than about3″, less than about 1″ and less then about ½″.

General teachings regarding optics to provide annular beam patterns areprovided in D. Zeng, Annular Beam Shaping and Optical Trepanning,Thesis, College of Engineering and Computer Science, University ofCentral Florida (2006), the entire disclosure of which is incorporatedherein by reference.

Turning to FIG. 12 there is shown an embodiment of an optics assembly toprovide a cylindrical beam pattern. A collimated circular laser beamshown by ray trace lines 1200 enters a axicon lens 1201 where it isformed into an expanding annular (hollow cone) pattern 1202, whichenters a lens 1203, that shapes the beam into a cylindrical beam 1204. Aplan view cross section for the cylindrical beam 1004 is shown withrespect to a tubular having an inner work surface 1005. Although shownas a collimated beam entering the axicon, the beam may also be divergingor converging, and may have a Gaussian distribution or otherdistributions.

Turning to FIGS. 13A and 13B there is shown an embodiment of an opticsassembly to provide a radially extending laser beam pattern of aplurality of laser beams. A laser beam, shown by ray trace lines 1301,preferably collimated, is directed toward a multifaceted optic 1302,which in this embodiment has four faces 1302 a, 1302 b, 1302 c, 1302 d.Each face directs a laser beam 1301 a, 1301 b, 1301 c, 1301 drespectively away from the optic 1302 in a radially extending patterntoward a works surface. The multifaceted optic may have n=1, n=2, n=3,n−4 (as shown in FIGS. 13A and 13B), n=5, n=6, and greater, until n=∞(e.g., becoming essentially a reflective cone). The number of laserbeams (which can viewed as spokes on a wheel extending from the optic)is equal to “n,” i.e., a radially extending bean for every face. Theradially extending beams may be at any angle with respect to the axial,i.e., incoming beam. Thus they may be at about 90°, about 45° and anglesgreater and less than those angles. The faces may also have beam shapingand characterizing properties, such as having a focusing surface.Preferably all of the faces have similar, or the same beam shaping andcharacterizing properties, however they can be varied from one face tothe next to provide for a predetermined variable radial beam pattern.Depending upon the “n” number, the power of the laser beam, the natureof the material to be removed, and other factors the optics assembly mayneed to be rotated or may be able to accomplishes the removal of thetargeted material without requirement rotation.

Turning to the embodiment of FIGS. 14, 14A, and 14B there is provided anembodiment of a laser head and optics assembly. The laser head 1400 hasan outer body 1405 that has three openings 1402, 1403, 1403. The laserbeam in a linear pattern is propagated through those openings. The head1400 has an optics assembly 1410 that has a laser beam receiving orinput face 1411 and three angular laser beam launch members 1412, 1413,1414. Each laser beam launch member has a laser beam launch face 1417,1416, and 1415. Turning to FIG. 14B, which by way of example shows across sectional view of angular launch member 1412, the member has faces1420, 1421, 1422 1423 (and side faces not shown) that reflect and thusdirect the laser beam to and out of face 1417. These reflective facesmay be obtained through the use of total internal reflection (TIR),reflected coatings, and combinations and variations of these. The launchfaces, e.g., 1417, of the optics assembly needs to be protected fromdirt and debris. This may be accomplished by several means. For example,the faces may be slightly recessed within the body 1405 of the head 1400with channels in, or associated with, the body directing a fluid acrossand away from the face. The face may be optically coupled to or havewithin it micro channels that are configured to form fluid jets intowhich the laser beam is coupled in the microchannel. A fluid streamcould be flowed annularly down, or more preferably up, to help clearaway debris along the surface of the tool. Three staggered launch facesare shown in the embodiment of FIG. 14. It should be understood thatmore or less launch faces and launch members may be employed, that thesemembers may obtain their laser energy for a single optical fiber,multiple fibers, or each having their own associated fiber, and thatthem may be arranged a long a line, or in other patterns. The tool headmay be attached to, or associated with a down hole tool assembly havinga centralizer and an advancement device, and for example, could beassociated with any of the types and configurations of down hole toolsand assemblies in this specification. This laser head has the capabilityof having very small outside diameters, and thus has the capability ofbeing configured for use in tubulars, channels, passages or pipes thathave an internal diameter of less then about 3″, less then about 2″,less than about 1″ and smaller.

The optics assemblies of the embodiments of FIGS. 9, 10, 12, 13A & B,and 14B can be utilized for example, in the various embodiments of toolsprovided in this specification, including the optics packages and toolsof the type disclosed and taught in US Patent Application PublicationNos. 2012/0074110 and 2012/0273470, and in Ser. No. 13/403,509,13/782,869, and 13/768,149, the entire disclosures of each of which areincorporated herein by references, as well as other types of down holetools and assemblies that are sufficient to protect and hold the opticspackages and deliver it to the intended work area.

EXAMPLES

The following examples are provide to illustrate various devices, tools,configurations and activities that may be performed using the high powerlaser tools, devices and system of the present inventions. Theseexamples are for illustrative purposes, and should not be viewed as, anddo not otherwise limit the scope of the present inventions.

Example 1

A metal work surface has a barium sulfate deposit covering it. Thedeposit averages about 0.18″ thick. A CW laser beam having a wavelengthof about 1070 nm, a power of about 6 kW, a power density at the spot onthe work surface of about 4.6 W/cm², and a spot size diameter at thework surface of about 12.7 mm, is scanned across the deposit at a rateof about 0.55 in/sec. The laser beam substantially removes the bariumsulfate material from the metal work surface, cutting an about 1.6″ deepby 0.7″ wide trough in the deposit.

Example 2

A metal work surface has a barium sulfate deposit covering it. Thedeposit averages about 0.18″ thick. A CW laser beam having a wavelengthof about 1070 nm, a power of about 6 kW, a power density at the spot onthe work surface of about 4.6 W/cm², and a spot size diameter at thework surface of about 12.7 mm, is scanned across the deposit at a rateof about 0.37 in/sec. The laser beam removes the barium sulfate materialfrom the metal work surface, cutting an about 1.8″ deep by 0.7″ widetrough in the deposit.

Example 3

A metal work surface has a calcium sulfate deposit covering it. Thedeposit averages about 0.25″ thick. A CW laser beam having a wavelengthof about 1070 nm, a power of about 6 kW, a power density at the spot onthe work surface of about 4.6 W/cm², and a spot size diameter at thework surface of about 12.7 mm, is scanned across the deposit at a rateof about 0.55 in/sec. The laser beam substantially removes the calciumsulfate material from the metal work surface, cutting an about 1.9″ deepby 0.7″ wide trough in the deposit.

Example 4

A metal work surface has a calcium carbonate deposit covering it. Thedeposit averages about 0.25″ thick. A CW laser beam having a wavelengthof about 1070 nm, a power of about 6 kW, a power density at the spot onthe work surface of about 4.6 W/cm², and a spot size diameter at thework surface of about 12.7 mm, is scanned across the deposit at a rateof about 0.55 in/sec. The laser beam substantially removes the calciumsulfate material from the metal work surface, cutting an about 1.9″ deepby 0.7″ wide trough in the deposit.

Example 5

A metal work surface has a paraffin wax deposit covering it. The depositaverages about 0.25″ thick. A CW laser beam having a wavelength of about1070 nm, a power of about 6 kW, a power density at the spot on the worksurface of about 4.6 W/cm², and a spot size diameter at the work surfaceof about 12.7 mm, is scanned across the deposit at a rate of about 0.55in/sec. The laser beam quickly melts and liquefies the paraffin wax onthe work surface, does not structurally damage the work surface, and theliquefied paraffin wax flows from the work surface.

Example 6

A oil well located in the Gulf of Mexico is located in a water depth ofabout 2,000 feet and has a production tubing that extends to a totalvertical depth of about 15,000 ft, at which point there is a productionzone, having perforations and screens. The well has been producing aknown number of barrels of crude per day for the last 3 years. Recentlythe production has dropped of significantly. Upon inspection it isdetermined that about 2,000 feet of the production tubing is 60%occluded, i.e. the internal diameter has been reduced by the blockage by60%, with a scale that is primarily made up of Barium Sulfate. A laserflow assurance system is deployed to the well site. The system has a 20kW laser and supporting systems, an umbilical having a high power longdistance optical fiber having a core size of about 600 μm and anattenuation of about 1 dB/km. The system has a laser delivery tool ofthe type shown in herein. The system is moved into position and the toolis advanced into the well. Upon reaching the location where the depositis located the laser is fired delivery the high power laser beam to theinner diameter of the production tubing ablating the blockage withoutsubstantially damaging the tubing. The tool is advanced until the entire2,000 ft. of obstructed pipe is cleared and the production of the wellis returned to the original known production of barrels per day.

Example 7

A well has an occlusion and chemicals that can be active by a laser areused to treat the well providing a laser-chemical treatment, which issynergistic.

Example 8

The laser tools of the present inventions can be used to treat boilersand desalinization equipment.

Example 9

Using a pulsed laser as the source of laser energy in a laser flowassurance operations. A typical pulsed laser may be a semiconductorlaser or a fiber laser operating in a pulsed mode. The pulse from thepulsed laser having a pulse characteristic of a 5 kHz modulation ratewith a 10%-50% duty cycle.

Example 10

A down hole laser delivery tool is used to remove a deposit from aperforation zone in a well and to reopen fouled perforations. Turning toFIGS. 7A and 7B there is shown a schematic cross section of a down holelaser tool 700 in a casing 750 in a well bore. The down hole laser tool700 has ports 703, circulating ports, for delivering a circulationfluid, e.g., gas, liquid or both, to assist in carrying away and out ofthe well any removed material. As shown in FIG. 7A the laser toll isbeing advanced toward the perforations 751 in the casing 750, which hasbeen fouled by build up 752. Upon reaching the build up area the lasertool fires the laser beam 702 at the build up causing its removal. Thelaser beam is scanned around the inner diameter of the casing to removeall of the build up. Based upon sensors in the laser tool when the laserbeam reaches a perforation 751, scanning of the beam is suspended andthe beam is held on the perforation until it is cleared of the build up.

Example 11a

Hydrates form at low-temperature, high-pressure in the presencehydrocarbons and water. Hydrate formation can plug flow lines, equipmentand other structures and devices used in deep water offshore hydrocarbonexploration and production. The kinetics of hydrate formation isdependent upon, among other things the nature of the crude oil beingproduced. Thus, the rate of hydrate formation may be very different fromwell to well, or as other factors change on a single well. To address,mitigate and manage hydrate related problems there is provided a methodof positioning a high power laser tool, for example a laser cutter or alaser illuminator in the areas where hydrate formation is likely, whereflow assurance is critical, where hydrate formation has been detected orobserved and combinations thereof. The laser tool is connected to a highpower laser, preferably on the surface, by way of a high power lasercable. The high power laser energy is then delivered to heat, melt,and/or abate the hydrate formation, for example by heating thestructure, by maintaining the structure at a certain level, preferablyabove a temperature at which hydrate formation can occur, by directlyheating, cutting melting, or ablating the hydrate, and combinations ofthe foregoing.

A preferred wavelength for treating and managing hydrate formation wouldbe about 1.5 μm or greater, more preferably from about 1.5 μm to about 2μm, which is a wavelength range that can be transmitted down the fiberover great lengths without substantial power losses, and is also awavelength range that is preferentially absorbed by the hydrate.

Example 11b

A submersible assembly, e.g., an ROV, with a laser tool for directing alaser beam directs a high power laser beam to a subsea structure, suchas for example, a manifold, a wellhead, a pump, a pipe, a pipeline, atree, a conductor, or a BOP. The high power laser beam heats thestructure preventing, removing, or mitigating hydrate formation.Examples, of ROVs with laser tools, and sub sea laser ROV operations,including the removal of hydrates, are taught and disclosed in US PatentPublication No. 2012/0266803 the entire disclosure of which isincorporated herein by reference. Preferably, for example, the lasertool can deliver a high power laser beam having a wavelength of lessthan about 800 nm, and from about 400 nm to about 800 nm. High powerlaser beams within these wavelength ranges can be provided by, forexample, solid state lasers, semiconductor lasers and fiber lasers.

Example 12

In this embodiment of a high power laser system, there is provided theuse of high power laser energy, the use of high power laser opticalcables for powering, controlling and/or monitoring equipment andcomponents, and/or the use of remote high power laser tools, to providea system for removing paint. This system would provide the addedadvantage that it would eliminate the waste, noise and otherenvironmental issues, with conventional abrasive, mechanical or chemicalpaint removal techniques. This system would also provide the ability toremove paint, or other coatings, from areas that are remote, distant orotherwise difficult to access.

Example 13

A high power laser down hole tool having a laser cutting head of thetype disclose and taught by US Patent Applications Publication No.2012/0074110 and Ser. Nos. 13/782,869, and 13/768,149, (the entiredisclosures of each of which are incorporated herein by reference) isused to cut off a fouled tail pipe section of a production tubing.Turning to FIG. 8A, 8B, an 8C there are shown cross sectional views ofsnap shots of an embodiment of this processes. The laser tool assemblyhas a tractor assembly with a centralizer 802, a motor andcommunications housing 803, a scraper 804, and a laser head 805. Thelaser tool is seen in side of a production tubing 801 that is locatedinside of a well casing 800. the production tubing 801 has a build up807 that is blocking flow from perforations 808. As shown in FIG. 8B thelaser tool is advanced past the packer 806 and to the point of the buildup 807, where the laser is fired and delivered to the pipe to cut offthe clogged lower section, after which the laser tool is withdrawn, asshown in FIG. 8C.

Example 14

Turning to FIGS. 15A to 15C there are shown three cross sectionalschematics of an embodiment of a laser follow assurance application foran existing completion assembly. the existing completion assembly 1510has a temperature transition area 1512 that results in the formation ofdeposits in area 1511. An anchor 1505 is set in the production tubing1501, at an appropriate location in the area of the deposit 1511 and thearea of the temperature transition 1512, and preferably toward the lowerarea of the temperature transition area 1512 as shown in FIG. 15B. thelaser heating element 1503 has a tool latch 1504 at its distal end andis connected to an umbilical 1502 having for example a electric line,high power optical fiber, data lines etc. The laser heating element 1503is lowered by the umbilical 1502 so that the tool latch 1504 engages andis held in place by anchor 1505. In operation the hydrocarbons flowthrough the laser heating element which keeps the temperature above thepoint where deposit formation is likely.

Example 15

Turning to FIGS. 16 and 16A there is provided a longitudinal crosssectional and transverse cross sectional schematic (taken along lineA-A) views, respectively, of an embodiment of a laser heating tool 1600for use in an existing completion, which for example could be used inExample 14. The laser heating tool 1600 has a sealed closed loop laserheating system. A laser optic fiber 1610 connects to (is in opticalcommunication with) a laser optics assembly 1608 that shapes anddelivers the laser beam 1607 to a beam dump 1609, which serves as aheating element. Closed loop heating channels 1604, have tubes 1602 thatcontain a heat transport fluid. The closed loop heating channels 1604extend into, or are otherwise in thermal communication with the beamdump 1606 and with fins 1601. In operation, as the laser energy isabsorbed and generates heat in the beam dump, the fluid in the tubeswill heat, and preferably reach a boiling point. This heating will causea circulation to occurring with the fluid flowing around the heatingchannels. Temperature sensors 1605, 1606 are provided to monitor andcontrol the heating and circulating of the fluid. The closed loopheating channels 1604 and their tubes 1602 are associated with fins1601. In this manner, the fins 1601 are be heated by the circulatingfluid. Hydrocarbons flow through channels 1603 and are heated by thefins 1601.

Example 16

Turning to FIGS. 17 and 17A there is provided a longitudinal crosssectional and transverse cross sectional schematic (taken along lineA-A) views, respectively, of an embodiment of a laser heating tool 1700for use in an existing completion, which for example could be used inExample 14. The laser heating tool 1700 has a sealed closed loop laserheating system. A laser optic fiber 1711 connects to (is in opticalcommunication with) a laser optics assembly 1709 that delivers the laserbeam 1710 to a beam dump 1708, which serves as a heating element. Closedloop heating channels 1712, have tubes 1701 that contain a heattransport fluid. The closed loop heating channels 1712 extend into, orare otherwise in thermal communication with the beam dump 1708 and withfins 1703. In operation, as the laser energy is absorbed and generatesheat in the beam dump, the fluid in the tubes will heat, and preferablyreach a boiling point. An electric pump 1705 and a check valve 1706 areused to cause the fluid to circulate around the heating channels 1712.Temperature sensors 1706, 1607 are provided to monitor and control theheating and circulating of the fluid. The closed loop heating channels1712 and their tubes 1701 are associated with fins 1703. In this manner,the fins 1703 are be heated by the circulating fluid. Hydrocarbons flowthrough channels 1702 and are heated by the fins 1703.

Example 17

Turning to FIGS. 18, 18A and 18B there is shown an embodiment of a laserflow assurance assembly for use in a new completion. Turning to FIG. 18there is shown a cross section of the laser tool 1890 having a highpower laser fiber 1800, an electric powered fluid pump 1802, fluidfilled coils 1808 that are thermally associated with, and preferablymade from and in a high energy absorbent material 1810, and laser beampath chambers 1812, 1816. In this embodiment, two high power laserfibers, or a beam splitter, provide the laser beam to the opticsassemblies 1816, 1818. The fibers are connected to the optics byconnectors 1804, 1806. Fins 1820 are thermally associated with the fluidfilled coils 1808. The fins 1820 are located in the annuls between thehigh energy absorbent material 1810 and the outer housing 1880 of thetool 1890. In operation the fins are heated and the hydrocarbons flowthrough the annulus. The outer housing 1880, may not be present and theinner surface of the production tubing may service as the outer wall forthe channel that directs the flow of the hydrocarbons by the fins. FIG.18A is a cross section taken along line A-A, showing the fins andannulus (for clarity the inner comments of the tool are not shown inthis figure). FIG. 18 B shown the tool 1890 located in the productiontubing 1824. The tool 1890 has an umbilical 1826 having the opticalfiber(s), electric line, data lines, etc.

The tool can be built in sections of varying lengths, from several feet,to tens of feet, to longer, multiple sections, and with additionalfibers to meet the thermal requirements of the particular application,to enable the laser flow assurance assembly to reduce and preferablyeliminate any build up in the production tubing, or the targeted area ofthat tubing.

Example 18

Turning to FIGS. 19A to 19 c there is shown an embodiment of thedeployment of an embodiment of a laser flow assurance assembly in apipeline application. A laser heating tool 1901, with an umbilical 1910,is deployed in a pipeline 1904 by way of a pig 1902. The pig 1902 isdetached and the laser beam 1903 is fired. The tool 1901 heats thepipeline material as it flows by the tool. The tool 1901 can berecovered by pumping the pig 1902 a back to the tool 1901, attaching andrecovering.

Example 19

Turning to FIG. 20 there is shown a cross sectional view of anembodiment of a laser flow assurance tool 2000 for an embodiment of apipeline 2004 application. The tool 2000 has electronic actuated slips2008, 2009 that provide for the predetermined and precise placement ofthe tool 2000 in the pipeline 2004. The tool 2000 has an umbilical 2007,which could be a wireline and associated electrical, high power opticalfiber and data lines. The tool 2000 has an electric motor-check valveassembly 2006, temperature sensors 2005, 2003, an optics package 2001and a laser beam path 2002 along with the laser beam travels. Theoperation of this tool 2000, and the other components of this tool, arealong the lines of the tool in Example 16.

The tool can be built in sections of varying lengths, from several feet,to tens of feet, to longer, multiple sections, and with additionalfibers to meet the thermal requirements of the particular application,to enable the laser flow assurance assembly to reduce and preferablyeliminate any build up in the pipeline, or the targeted area of thatpipeline.

Example 20

Turning to FIGS. 21 and 21A there is shown a cross sectionallongitudinal view (FIG. 21) and a transverse cross sectional view (inthe open position) (FIG. 21A) of an embodiment of an external pipeline2102 laser flow assurance assembly 2190. The assembly has a wirelineumbilical 2109, an insulating protective cover 2108, a fiber connector2107, and optics package 2110 and a fluid filled heating coil assembly2105, which has its upper section in thermal communication with a highenergy absorbent material 2104 that has a laser beam path chamber 2103and a fluid tank 2101. The assembly has a swing hinge 2112, which allowsfor the opening of an insulated protective cover 2110, 2111.

The assembly can be built in sections of varying lengths, from severalfeet, to tens of feet, to longer, multiple sections, and with additionalfibers to meet the thermal requirements of the particular application,to enable the laser flow assurance assembly to reduce and preferablyeliminate any build up in the pipeline, or the targeted area of thatpipeline.

In addition to these, examples, the high power laser systems, tools,devices and methods of the present inventions may find other uses andapplications in activities such as: off-shore activities; subseaactivities; decommissioning structures such as, factories, nuclearfacilities, nuclear reactors, pipelines, bridges, etc.; cutting andremoval of structures in refineries; civil engineering projects andconstruction and demolitions; concrete repair and removal; mining;surface mining; deep mining; rock and earth removal; surface mining;tunneling; making small diameter bores; oil field perforating; oil fieldfracking; well completion; precise and from a distance, in-place millingand machining; heat treating; and combinations and variations of theseand other activities and operations.

The laser tools and down hole processes may also find application inother laser and laser assisted processes in, or associated with aborehole. For example the laser tools and processes may find applicationin lost circulation events. In this situation the drilling mud flowsinto the formation and will not return up the borehole. A polymer, orother material that interacts with the laser beams energy, wavelength orboth, can be sent down the hole, this material is then alerted, unwound,expands, is release or melts or otherwise plugs that area where the lostcirculation is occurring thus return the well to normal operations. Anadditional example would be the use of these laser tools and down holeprocesses to perform in situ refining of the hydrocarbons in the wellbore, or in a pipe line as they are transported.

A single high power laser may be utilized in the system, tools andoperations, or there may be two or three high power lasers, or more.High power solid-state lasers, specifically semiconductor lasers andfiber lasers are preferred, because of their short start up time andessentially instant-on capabilities. The high power lasers for examplemay be fiber lasers or semiconductor lasers having 10 kW, 20 kW, 50 kWor more power and, which emit laser beams with wavelengths in the rangefrom about 455 nm (nanometers) to about 2100 nm, preferably in the rangeabout 800 nm to about 1600 nm, about 400 nm to about 800 nm, about 1060nm to 1080 nm, 1530 nm to 1600 nm, 1800 nm to 2100 nm, and morepreferably about 1064 nm, about 1070-1080 nm, about 1360 nm, about 1455nm, 1490 nm, or about 1550 nm, or about 1900 nm (wavelengths in therange of 1900 nm may be provided by Thulium lasers).

An example of this general type of fiber laser is the IPG YLS-20000. Thedetailed properties of which are disclosed in US patent applicationPublication Number 2010/0044106.

Examples of lasers, conveyance structures, high power laser fibers, highpower laser systems, optics, optics housings to isolate optics fromvibration and environment conditions, break detection and safetymonitoring, control systems, connectors, cutters, and other laserrelated devices, systems and methods that may be used with, in, or inconjunction with, the various embodiments of devices systems, tools,activities and operations set forth in this specification are disclosedand taught in the following US patent application publications and USpatent applications: Publication Number 2010/0044106; Publication Number2010/0044105; Publication Number 2010/0044103; Publication Number2010/0215326; Publication Number 2012/0020631; Publication Number2012/0074110; Publication No. 2012/0068086; Publication No.2012/0248078; Ser. No. 13/403,723; Ser. No. 13/403,509; Ser. No.13/486,795; Ser. No. 13/565,345; Ser. No. 61/605,429; Ser. No.61/605,434; Ser. No. 13/782,869; and, Ser. No. 13/768,149, the entiredisclosures of each of which are incorporated herein by reference.

In addition to the use of high power electromagnetic energy, such ashigh power laser beams, other forms of directed energy or means toprovide the same, may be utilized in, in addition to, or in conjunctionwith the devices systems, tools, activities and operations set forth inthis specification. Such directed energy could include, for example,non-optical stimulated emission electromagnetic energy, non-opticalcoherent electromagnetic energy, microwaves, sound waves, millimeterwaves, plasma, electric arcs, flame, flame jets, steam and combinationsof the foregoing, as well as, water jets and particle jets. It is noted,however, that each of these other such directed energies, hassignificant disadvantages when compared to high power laser energy.Nevertheless, the use of these other less preferred directed energymeans is contemplated by the present inventions as directed energymeans.

Generally, the laser systems and techniques of the present inventionscan be, in part, directed to the cleaning, resurfacing, removal, andclearing away of unwanted materials, e.g., build-ups, deposits,corrosion, or substances, in, on, or around structures, e.g. the workpiece, or work surface area. Such unwanted materials would include byway of example rust, corrosion, corrosion by products, degraded or oldpaint, degraded or old coatings, paint, coatings, waxes, NORM, hydrates,microbes, residual materials, biofilms, tars, sludges, and slimes. Thelaser energy of sufficient power and characteristics can be transportedover great lengths and delivered to remote and difficult to accesslocations. In addition to the field of flow assurance, the presentinventions would also find many applications and uses in other fields.Moreover, the present inventions would have uses and applications beyondoil, gas, geothermal and flow assurance, and would be applicable to the,cleaning, resurfacing, removal and clearing away of unwanted materialsin any location that is far removed from a laser source, or difficult toaccess by conventional technology as well as assembling and monitoringstructures in such locations.

The laser tools and systems may also have, or include a laser monitoringtool for illuminating a surface of a work piece to detect surfaceanomalies, cracks, corrosion, etc. In this type of laser monitoringtool, the laser beam may be scanned as a spot, or other shape, along thesurface of the work area, in a pattern, or it may be directed to asurface in a continuous line that impacts some or all of the innercircumference of the inner wall of the work piece. The light reflect byand/or absorbed by the surface would then be analyzed to determine ifany anomalies were present, identify their location and potentiallycharacterize them. A laser radar type of system may be used for thisapplication, a laser topographic system may be used for thisapplication, as well as, other known laser scanning, measuring andanalyzing techniques. The laser tool may also be, or have, a lasercutter that is used to remove unwanted material from a surface, cut ahole through, or otherwise remove a section of materials, such asmilling a window in a well casing, or weld a joint between two sectionsof a structure, or repair a grout line between two section of structureby for example activating a heat activated grout material. The lasertool may be a laser illumination tool that provides sufficient highpower laser energy to an area of the surface to kill or remove microbesand microbial related materials such as a biofilm. This type of laserillumination tool may also be used to clear and remove other materials,such as waxes, from an interior surface of for example a tank, apipeline or a well. Combinations of laser tools, e.g., a cutter, anilluminator, a measurement tool, and non-laser tools, may be utilized ina single assembly, or they may be used in separate assemblies that areused sequentially or in parallel activities.

The various embodiments of devices systems, tools, activities andoperations set forth in this specification may be used with various highpower laser systems and conveyance structures and systems, in additionto those embodiments of the Figures in this specification. The variousembodiments of devices systems, tools, activities and operations setforth in this specification may be used with: other high power lasersystems that may be developed in the future: with existing non-highpower laser systems, which may be modified, in-part, based on theteachings of this specification, to create a high power laser system;and with high power directed energy systems. Further, the variousembodiments of devices systems, tools, activities and operations setforth in this specification may be used with each other in different andvarious combinations. Thus, for example, the configurations provided inthe various embodiments of this specification may be used with eachother; and the scope of protection afforded the present inventionsshould not be limited to a particular embodiment, configuration orarrangement that is set forth in a particular embodiment, example, or inan embodiment in a particular Figure.

It is also noted that the laser systems, methods, tools and devices ofthe present inventions may be used in whole or in part in conjunctionwith, in whole or in part in addition to, or in whole or in part as analternative to existing methodologies for, e.g., monitoring, welding,cladding, annealing, heating, cleaning, drilling, advancing boreholes,controlling, assembling, assuring flow, drilling, machining, poweringequipment, and cutting without departing from the spirit and scope ofthe present inventions. Additionally, it is noted that the sequence ortiming of the various laser steps, laser activities and laser methods(whether solely based on the laser system, methods, tools and devices orin conjunction with existing methodologies) may be varied, repeated,sequential, consecutive and combinations and variations of these,without departing from the spirit and scope of the present inventions.

The invention may be embodied in other forms than those specificallydisclosed herein without departing from its spirit or essentialcharacteristics. The described embodiments are to be considered in allrespects only as illustrative and not restrictive.

What is claimed:
 1. A high power laser system for performing laseroperation on a material in a borehole, the system comprising: a. a highpower laser having the capability of providing a laser beam having atleast about 20 kW of power; b. a long distance high power transmissioncable for providing the high power laser energy deep within a boreholehole; and, c. a high power laser tool having a high power laser optic toprovide an annular laser beam pattern.
 2. A high power laser system forperforming in situ high power laser processing of a material in aborehole, the system comprising: a. a laser capability of providing alaser beam having at least about 20 kW of power; b. a long distance highpower transmission cable for transmitting the high power laser; c. ahigh power in situ processing laser tool optically associated with thetransmission cable and the laser; d. the laser tool positioned in theborehole adjacent an area of likely flow impediment; and, e. the highpower laser tool comprising: (i) a high power laser optic to provide thelaser beam in a laser beam pattern and along a laser beam path; (ii) alaser flow passage, the flow passage configured to, at least in part,operationally influence a flowing hydrocarbons in the borehole; f.wherein the laser beam path, at least in part, travels through the laserflow passage, whereby flowing hydrocarbons are capable of beingprocessed by the laser beam delivered along the laser beam path in thelaser beam pattern.
 3. The high power laser system for performing insitu high power laser processing of flowing material in a borehole ofclaim 2, wherein the laser tool is located at least about 1,000 feetfrom a surface of the borehole.
 4. The high power laser system forperforming in situ high power laser processing of flowing material in aborehole of claim 2, wherein the laser tool is located at least about2,000 feet from a surface of the borehole.
 5. The high power lasersystem for performing in situ high power laser processing of flowingmaterial in a borehole of claim 2, wherein the laser tool is located atleast about 3,000 feet from a surface of the borehole.
 6. The high powerlaser system for performing in situ high power laser processing offlowing material in a borehole of claim 2, wherein the laser tool islocated at least about 1,000 feet from a surface of the borehole and thesystem comprises a second high power laser tool comprising a high powerlaser optic to provide the laser beam in a laser beam pattern and alonga laser beam path, a laser flow passage, the flow passage configured to,at least in part, operationally influence the flowing hydrocarbons inthe borehole.
 7. The high power laser system for performing in situ highpower laser processing of flowing material in a borehole of claim 2,wherein the laser tool is located at least about 1,000 feet from asurface of the borehole and the system comprises a polished stinger suband a sealing member.
 8. The high power laser system for performing insitu high power laser processing of flowing material in a borehole ofclaim 2, wherein the laser tool is located at least about 10,000 feetfrom a surface of the borehole and the system comprises a polishedstinger sub, a sealing member, and a second high power laser toolcomprising a high power laser optic to provide the laser beam in a laserbeam pattern and along a laser beam path, a laser flow passage, the flowpassage configured to, at least in part, operationally influence theflowing hydrocarbons in the borehole and a third high power laser toolcomprising a high power laser optic to provide the laser beam in a laserbeam pattern and along a laser beam path, a laser flow passage, the flowpassage configured to, at least in part, operationally influence theflowing hydrocarbons in the borehole.
 9. The high power laser system forperforming in situ high power laser processing of flowing material in aborehole of claim 2, wherein hydrocarbons are flowing in the boreholeand the flowing hydrocarbon has at least about 0.4 wt % asphaltene. 10.The high power laser system for performing in situ high power laserprocessing of flowing material in a borehole of claim 2, whereinhydrocarbons are flowing in the borehole and wherein the flowinghydrocarbon has at least about 1 wt % asphaltene.
 11. The high powerlaser system for performing in situ high power laser processing offlowing material in a borehole of claim 2, wherein hydrocarbons areflowing in the borehole and the flowing hydrocarbon has at least about1.2 wt % asphaltene.
 12. The high power laser system for performing insitu high power laser processing of flowing material in a borehole ofclaim 2, wherein hydrocarbons are flowing in the borehole and theflowing hydrocarbon has at least about 4 wt % asphaltene.
 13. The highpower laser system for performing in situ high power laser processing offlowing material in a borehole of claim 2, wherein hydrocarbons areflowing in the borehole and the flowing hydrocarbon has at least about 6wt % asphaltene.
 14. The high power laser system for performing in situhigh power laser processing of flowing material in a borehole of claim2, wherein hydrocarbons are flowing in the borehole and the flowinghydrocarbon has at least about 10 wt % asphaltene.
 15. The high powerlaser system for performing in situ high power laser processing offlowing material in a borehole of claim 2, wherein the system is capableof increasing the S-value of the flowing hydrocarbon by at about 0.05.16. The high power laser system for performing in situ high power laserprocessing of flowing material in a borehole of claim 2, wherein thesystem is capable of increasing the S-value of the flowing hydrocarbonby at about 0.01.
 17. The high power laser system for performing in situhigh power laser processing of flowing material in a borehole of claim2, wherein the system is capable of increasing the S-value of theflowing hydrocarbon by at about 0.02.
 18. The high power laser systemfor performing in situ high power laser processing of flowing materialin a borehole of claim 2, wherein the system is capable of increasingthe S-value of the flowing hydrocarbon by at about
 1. 19. The high powerlaser system for performing in situ high power laser processing offlowing material in a borehole of claim 2, wherein the system is capableof increasing the S-value of the flowing hydrocarbon by at about
 2. 20.The high power laser system for performing in situ high power laserprocessing of flowing material in a borehole of claim 3, whereinhydrocarbons are flowing in the borehole and the flowing hydrocarbon hasat least about 0.4 wt % asphaltene.
 21. The high power laser system forperforming in situ high power laser processing of flowing material in aborehole of claim 4, wherein hydrocarbons are flowing in the boreholeand wherein the flowing hydrocarbon has at least about 1 wt %asphaltene.
 22. The high power laser system for performing in situ highpower laser processing of flowing material in a borehole of claim 6,wherein hydrocarbons are flowing in the borehole and the flowinghydrocarbon has at least about 1.2 wt % asphaltene.
 23. The high powerlaser system for performing in situ high power laser processing offlowing material in a borehole of claim 6, wherein hydrocarbons areflowing in the borehole and the flowing hydrocarbon has at least about 4wt % asphaltene.
 24. The high power laser system for performing in situhigh power laser processing of flowing material in a borehole of claim3, wherein the system is capable of increasing the S-value of theflowing hydrocarbon by at about 0.05.
 25. The high power laser systemfor performing in situ high power laser processing of flowing materialin a borehole of claim 6, wherein the system is capable of increasingthe S-value of the flowing hydrocarbon by at about 0.01.
 26. The highpower laser system for performing in situ high power laser processing offlowing material in a borehole of claim 6, wherein the system is capableof increasing the S-value of the flowing hydrocarbon by at about 0.02.27. A high power laser system for performing in situ high power laserprocessing of flowing material in a borehole, the system comprising: a.a high power laser capable of delivering a high power laser beam; b. ahigh power in situ processing laser tool optically associated with thetransmission cable and positioned in the borehole; and, c. the highpower laser tool comprising a high power laser optic to provide thelaser beam in a laser beam pattern and along a laser beam path, a laserflow passage, the flow passage configured to, at least in part, channela flowing hydrocarbons in the borehole; d. wherein the laser beam path,at least in part, travels through the flow passage, whereby the flowinghydrocarbons are capable of being processed by the laser beam deliveredalong the laser beam path in the laser beam pattern.
 28. The high powerlaser system for performing in situ high power laser processing offlowing material in a borehole of claim 27, wherein the laser tool islocated at least about 5,000 feet from a surface of the borehole. 29.The high power laser system for performing in situ high power laserprocessing of flowing material in a borehole of claim 27, whereinhydrocarbons are flowing in the borehole and the flowing hydrocarbon hasat least about 0.4 wt % asphaltene.
 30. The high power laser system forperforming in situ high power laser processing of flowing material in aborehole of claim 27, wherein hydrocarbons are flowing in the boreholeand the flowing hydrocarbon has at least about 1.2 wt % asphaltene. 31.The high power laser system for performing in situ high power laserprocessing of flowing material in a borehole of claim 27, whereinhydrocarbons are flowing in the borehole and the flowing hydrocarbon hasat least about 4 wt % asphaltene.
 32. The high power laser system forperforming in situ high power laser processing of flowing material in aborehole of claim 27, wherein the system is capable of increasing theS-value of the flowing hydrocarbon by at about 0.05.
 33. The high powerlaser system for performing in situ high power laser processing offlowing material in a borehole of claim 27, wherein the system iscapable of increasing the S-value of the flowing hydrocarbon by at about0.02.
 34. The high power laser system for performing in situ high powerlaser processing of flowing material in a borehole of claim 27, whereinthe system is capable of increasing the S-value of the flowinghydrocarbon by at about
 1. 35. A high power laser system for performingin situ high power laser processing of a material in a borehole, thesystem comprising: a. a high power laser system associated with aborehole, the borehole producing flowing hydrocarbons; the high powerlaser system having the capability of providing a laser beam having atleast about 10 kW of power; b. the high power laser system having a longdistance high power transmission cable for transmitting the high powerlaser; c. a high power in situ processing laser tool opticallyassociated with the transmission cable and positioned in the boreholeadjacent an area of the borehole having a flow impediment material; and,d. the high power laser tool comprising a high power laser optic toprovide the laser beam in a laser beam pattern and along a laser beampath, the laser beam path intersecting a borehole sidewall; e. whereinthe laser beam path, at least in part, travels through a flow impedimentmaterial, whereby the flow impediment material is removed withoutdamaging the sidewall of the borehole.
 36. The high power laser systemfor performing in situ high power laser processing of a material in aborehole of claim 35, wherein the flow impediment material comprises aprecipitate
 37. The high power laser system for performing in situ highpower laser processing of a material in a borehole of claim 35, whereinthe flow impediment material comprises an asphaltene.
 38. The high powerlaser system for performing in situ high power laser processing of amaterial in a borehole of claim 35, wherein the flow impediment materialcomprises Barium Sulfate.
 39. The high power laser system for performingin situ high power laser processing of a material in a borehole of claim35, wherein the flow impediment material comprises a metal organiccompound.
 40. The high power laser system for performing in situ highpower laser processing of a material in a borehole of claim 35, whereinthe flow impediment material comprises a gas hydrate.
 41. The high powerlaser system for performing in situ high power laser processing of amaterial in a borehole of claim 35, wherein the flow impediment materialcomprises a clathrate hydrate.
 42. The high power laser system forperforming in situ high power laser processing of a material in aborehole of claim 35, wherein the flow impediment material comprises awax.
 43. The high power laser system for performing in situ high powerlaser processing of a material in a borehole of claim 35, wherein theflow impediment material comprises a solid.
 44. A high power lasersystem for performing in situ high power laser processing of a materialin a borehole, the system comprising: a. a long distance high powertransmission cable for transmitting the high power laser; b. a highpower in situ processing laser tool optically associated with thetransmission cable and positioned in the borehole; and, c. the highpower laser tool comprising a high power laser optic to provide thelaser beam in a laser beam pattern and along a laser beam path, thelaser beam path intersecting a borehole sidewall; d. wherein the laserbeam path, at least in part, travels through a flow impediment material,whereby the flow impediment material is removed without damaging thesidewall of the borehole.
 45. The high power laser system for performingin situ high power laser processing of a material in a borehole of claim44, wherein the flow impediment material comprises at least about a 10%blockage of a passage in the borehole.
 46. The high power laser systemfor performing in situ high power laser processing of a material in aborehole of claim 44, wherein the flow impediment material comprises atleast about a 20% blockage of a passage in the borehole.
 47. The highpower laser system for performing in situ high power laser processing ofa material in a borehole of claim 44, wherein the flow impedimentmaterial comprises at least about a 50% blockage of a passage in theborehole.
 48. The high power laser system for performing in situ highpower laser 20 processing of a material in a borehole of claim 44,wherein the flow impediment material comprises at least about a 90%blockage of a passage in the borehole.
 49. The high power laser systemfor performing in situ high power laser processing of a material in aborehole of claim 44, wherein the flow impediment material comprises atleast about a 10% blockage of a passage in the borehole and the flowimpediment material comprises a material selected from the groupconsisting of a precipitate, a solid, a paraffins, a wax, an asphaltene,a gas hydrate, a scale, Barium Sulfate, and calcium carbonate.
 50. Thehigh power laser system for performing in situ high power laserprocessing of a material in a borehole of claim 44, wherein the flowimpediment material comprises at least about a 20% blockage of a passagein the borehole and the flow impediment material comprises a materialselected from the group consisting of a precipitate, a solid, aparaffins, a wax, an asphaltene, a gas hydrate, a scale, Barium Sulfate,and calcium carbonate.
 51. The high power laser system for performing insitu high power laser processing of a material in a borehole of claim44, wherein the flow impediment material comprises at least about a 50%blockage of a passage in the borehole and the flow impediment materialcomprises a material selected from the group consisting of aprecipitate, a solid, a paraffins, a wax, an asphaltene, a gas hydrate,a scale, Barium Sulfate, and calcium carbonate.
 52. The high power lasersystem for performing in situ high power laser processing of a materialin a borehole of claim 44, wherein the flow impediment materialcomprises at least about a 75% blockage of a passage in the borehole andthe flow impediment material comprises a material selected from thegroup consisting of a precipitate, a solid, a paraffins, a wax, anasphaltene, a gas hydrate, a scale, Barium Sulfate, and calciumcarbonate.
 53. The high power laser system of claim 2, wherein the laserbeam pattern is annular.
 54. The high power laser system of claim 6,wherein the laser beam pattern is annular.
 55. The high power lasersystem of claim 27, wherein the laser beam pattern is annular.
 56. Thehigh power laser system of claim 30, wherein the laser beam pattern isannular.
 57. The high power laser system of claim 42, wherein the laserbeam pattern is annular.
 58. The high power laser system of claim 44,wherein the laser beam pattern is annular.
 59. The high power lasersystem of claim 2, wherein the laser beam pattern is scanned.
 60. Thehigh power laser system of claim 42, wherein the laser beam pattern isscanned.
 61. The high power laser system of claim 42, comprising aplurality of laser beam patterns.
 62. The high power laser system ofclaim 44, comprising a plurality of laser beam patterns.
 63. The highpower laser system of claim 2, wherein the laser beam pattern isselected from the group consisting of a radially expanding conical beampattern and a collimated circular beam pattern.
 64. The high power lasersystem of claim 2, wherein the optics is selected from a groupconsisting of a vaxicon and an axicon.
 65. The high power laser systemof claim 27, wherein the laser beam pattern is selected from the groupconsisting of a radially expanding conical beam pattern, a collimatedcircular beam pattern.
 66. The high power laser system of claim 27,wherein the optics is selected from a group consisting of a vaxicon andan axicon.
 67. The high power laser system of claim 30, wherein thelaser beam pattern is selected from the group consisting of a radiallyexpanding conical beam pattern and a collimated circular beam pattern.68. The high power laser system of claim 30, wherein the optics isselected from a group consisting of a vaxicon and an axicon.
 69. Thehigh power laser system of claim 42, wherein the laser beam pattern isselected from the group consisting of a radially expanding conical beampattern and a collimated circular beam pattern.
 70. The high power lasersystem of claim 42, wherein the optics is selected from a groupconsisting of a vaxicon and an axicon.
 71. The high power laser systemof claim 44, wherein the laser beam pattern is selected from the groupconsisting of a radially expanding conical beam pattern and a collimatedcircular beam pattern.
 72. The high power laser system of claim 44,wherein the optics is selected from a group consisting of a vaxicon andan axicon.
 73. A method of in situ high power laser processing offlowing material in a borehole, the method comprising: associating ahigh power laser system with a borehole, the borehole producing flowinghydrocarbons; the high power laser system having the capability ofproviding a laser beam having at least about 10 kW of power; the highpower laser system having a long distance high power transmission cablefor transmitting the high power laser; a high power in situ processinglaser tool optically associated with the transmission cable andpositioned in the borehole adjacent an area of likely flow impediment;and, the high power laser tool comprising a high power laser optic toprovide the laser beam in a laser beam pattern and along a laser beampath, a laser flow passage, the flow passage configured to, at least inpart, operationally influence the flowing hydrocarbons in the borehole;delivering the high power laser beam along the laser beam path whereinthe laser beam path, at least in part, travels through the flow passage,whereby the flowing hydrocarbons are processed by the laser.
 74. Amethod of in situ high power laser processing of a material in aborehole, the system comprising: associating a high power laser systemwith a borehole, the borehole producing flowing hydrocarbons; the highpower laser system having the capability of providing a laser beamhaving at least about 10 kW of power; the high power laser system havinga long distance high power transmission cable for transmitting the highpower laser; a high power in situ processing laser tool opticallyassociated with the transmission cable and positioned in the boreholeadjacent an area of the borehole having a flow impediment material; and,the high power laser tool comprising a high power laser optic to providethe laser beam in a laser beam pattern and along a laser beam path, thelaser beam path intersecting a borehole side wall; delivering the laserbeam along the laser beam path wherein the laser beam, at least in part,strikes the flow impediment material, whereby the flow impedimentmaterial is lessened.
 75. A high power laser system for performing insitu high power laser processing of flowing material in a tubular, thesystem comprising: a. a high power laser system associated with atubular, the tubular having a flowing material; the high power lasersystem having the capability of providing a laser beam having at leastabout 5 kW of power; b. the high power laser system having a longdistance high power transmission cable for transmitting the high powerlaser; c. a high power in situ processing laser tool opticallyassociated with the transmission cable and positioned in the tubularadjacent an area of likely flow impediment; and, d. the high power lasertool comprising a high power laser optic to provide the laser beam in alaser beam pattern and along a laser beam path, a laser flow passage,the flow passage configured to, at least in part, operationallyinfluence the flowing material in the tubular; e. wherein the laser beampath, at least in part, travels through the flow passage, whereby theflowing material is processed by the laser beam.
 76. The system of claim75, wherein the tubular is associated with a boiler.
 77. The system ofclaim 75, wherein the tubular is associated with a desalinizationsystem.
 78. The system of claim 75, wherein the tubular is a pipeline.79. The system of claim 75, wherein the tubular is associated with achemical processing plant.
 80. The system of claim 75, wherein thetubular is associated with a nuclear power plant.
 81. A high power lasersystem for performing in situ high power laser processing of a materialin a tubular, the system comprising: a. a high power laser systemassociated with a tubular, the tubular having a flowing material; thehigh power laser system having the capability of providing a laser beamhaving at least about 10 kW of power; b. the high power laser systemhaving a long distance high power transmission cable for transmittingthe high power laser; c. a high power in situ processing laser tooloptically associated with the transmission cable and positioned in thetubular adjacent an area of the tubular having a flow impedimentmaterial; and, d. the high power laser tool comprising a high powerlaser optic to provide the laser beam in a laser beam pattern and alonga laser beam path, the laser beam path intersecting tubular side wall;e. delivering a laser beam along the laser beam path, wherein the laserbeam path, at least in part, strikes the flow impediment material,whereby the flow impediment material is lessened.
 82. The system ofclaim 81, wherein the tubular is associated with a boiler.
 83. Thesystem of claim 81, wherein the tubular is associated with adesalinization system.
 84. The system of claim 81, wherein the tubularis a pipeline.
 85. The system of claim 81, wherein the tubular isassociated with a chemic processing plant.
 86. The system of claim 81,wherein the tubular is associated with a nuclear power plant.
 87. Amethod of in situ high power laser processing of a material in atubular, the system comprising: associating a high power laser systemwith a tubular; the high power laser system having the capability ofproviding a laser beam having at least about 10 kW of power; the highpower laser system having a long distance high power transmission cablefor transmitting the high power laser; a high power in situ processinglaser tool optically associated with the transmission cable andpositioned in the tubular adjacent an area of the borehole having a flowimpediment material; and, the high power laser tool comprising a highpower laser optic to provide the laser beam in a laser beam pattern andalong a laser beam path, the laser beam path intersecting a tubular sidewall; delivering the laser beam along the laser beam path wherein thelaser beam, at least in part, strikes the flow impediment material,whereby the flow impediment material is lessened.
 88. A method ofaddressing hydrate formation in subsea structures, the methodcomprising: positioning a submersible assembly adjacent to a subseastructure; the submersible assembly comprising a laser tool in opticalcommunication with a high power laser; the laser tool delivering a highpower laser beam to the subsea structure, wherein the high power laserbeam heats the subsea structure and thereby mitigates hydrate formation.89. The method of claim 88, wherein the subsea structure is comprises acomponent of a deep water offshore hydrocarbon production system. 90.The method of claim 88, wherein the submersible assembly is an ROV. 91.The method of claim 88, wherein the subsea structure is selected fromthe group consisting of a line, a flow line, a line along the sea floor,a tree, a manifold, a BOP, a riser, devices and equipment.
 92. Themethod of claim 88, wherein the wavelength of the laser is from about455 nm to about 2100 nm.
 93. The method of claim 88, wherein thewavelength is from about 400 nm to about 800 nm.
 94. The method of claim88, wherein the laser beam is delivered through a laser fluid jet.
 95. Amethod of mitigating hydrate formation in subsea flow lines, equipment,structures or devices in subsea oil fields, the method comprising: a.positioning an ROV, comprising a high power laser tool, near a subseastructure in a subsea oil field; and, b. heating an area of the subseastructure with a laser beam delivered from the high power laser tool; c.whereby the heating mitigates hydrate formation.
 96. The method of claim95, wherein the subsea structure is heated above a temperature forhydrate formation in the structure.
 97. The method of claim 95, whereinthe heating maintains the subsea structure at a predeterminedtemperature.
 98. The method of claim 95, wherein the predeterminedtemperature is above a temperature for hydrate formation in thestructure.
 99. The method of claim 95, wherein the wavelength of thelaser is from about 455 nm to about 2100 nm.
 100. The method of claim95, wherein the wavelength is from about 400 nm to about 800 nm. 101.The method of claim 95, wherein the laser beam is delivered through alaser fluid jet.
 102. The method of claim 95, wherein the hydratecomprises methane.
 103. The method of claim 88, wherein the hydratecomprises methane.